Page Range | 80563-80988 | |
FR Document |
Page and Subject | |
---|---|
81 FR 80987 - National Apprenticeship Week, 2016 | |
81 FR 80985 - Get Smart About Antibiotics Week, 2016 | |
81 FR 80983 - American Education Week, 2016 | |
81 FR 80688 - Response of Nuclear Power Plant Instrumentation Cables When Exposed to Fire Conditions-Test Plan | |
81 FR 80664 - Environmental Impact Statements; Notice of Availability | |
81 FR 80686 - Sunshine Act Meetings | |
81 FR 80592 - Stream Protection Rule; Final Environmental Impact Statement | |
81 FR 80706 - Sunshine Act Meeting | |
81 FR 80660 - Sunshine Act Meeting Notice | |
81 FR 80664 - Sunshine Act Meetings | |
81 FR 80637 - Antidumping or Countervailing Duty Order, Finding, or Suspended Investigation; Advance Notification of Sunset Reviews | |
81 FR 80635 - Foreign-Trade Zone 61-San Juan, Puerto Rico; Application for Subzone; Aceros de América, Inc.; San Juan, Puerto Rico | |
81 FR 80676 - The President's National Security Telecommunications Advisory Committee | |
81 FR 80634 - Foreign-Trade Zone (FTZ) 122-Corpus Christi, Texas; Notification of Proposed Production Activity; voestalpine Texas, LLC (Hot Briquetted Iron By-Products); Portland, Texas | |
81 FR 80635 - Approval of Subzone Status; ASICS America Corporation; Byhalia, Mississippi | |
81 FR 80635 - Approval of Expansion of Subzone 92B; Huntington Ingalls Industries; Pascagoula, Mississippi | |
81 FR 80675 - Agency Information Collection Activities: Submission for OMB Review; Comment Request; FEMA Preparedness Grants: Tribal Homeland Security Grant Program (THSGP) | |
81 FR 80641 - Smart Technologies Trade Mission to Taiwan and Hong Kong With an Optional Stop in Guangzhou (China) | |
81 FR 80717 - Agency Information Collection Activities: Revision of an Approved Information Collection; Comment Request; Company-Run Annual Stress Test Reporting Template and Documentation for Covered Institutions With Total Consolidated Assets of $50 Billion or More Under the Dodd-Frank Wall Street Reform and Consumer Protection Act | |
81 FR 80675 - Agency Information Collection Activities: Submission for OMB Review; Comment Request; FEMA Preparedness Grants: Urban Areas Security Initiative (UASI) Nonprofit Security Grant Program (NSGP) | |
81 FR 80707 - Delegation to the Assistant Secretary for Political-Military Affairs of Authority To Concur With the Secretary of Defense on Certain Actions | |
81 FR 80608 - Department of the Treasury Acquisition Regulations; Incremental Funding of Fixed-Price, Time-and-Material or Labor-Hour Contracts During a Continuing Resolution | |
81 FR 80624 - Addition of Nonylphenol Ethoxylates Category; Community Right-To-Know Toxic Chemical Release Reporting | |
81 FR 80662 - Certain New Chemicals or Significant New Uses; Statements of Findings for October 2016 | |
81 FR 80707 - Generalized System of Preferences: Import Statistics Relating to Competitive Need Limitations | |
81 FR 80593 - Allocations of Cross-State Air Pollution Rule Allowances From New Unit Set-Asides for the 2016 Compliance Year | |
81 FR 80677 - Meeting: Homeland Security Advisory Council | |
81 FR 80686 - Notice of Lodging of Proposed Consent Decree Under the Comprehensive Environmental Response, Compensation and Liability Act | |
81 FR 80669 - Notice of Adoption of Policy Statement on Historic Preservation and Community Revitalization | |
81 FR 80632 - Federal Economic Statistics Advisory Committee | |
81 FR 80633 - Federal Economic Statistics Advisory Committee Meeting | |
81 FR 80719 - Mutual to Stock Conversion; Community Savings, Caldwell, Ohio; Approval of Conversion Application | |
81 FR 80720 - Notification of Citizens Coinage Advisory Committee November 17, 2016, Public Meeting | |
81 FR 80653 - Environmental Management Site-Specific Advisory Board, Hanford | |
81 FR 80563 - Chief Compliance Officer Annual Report Requirements for Futures Commission Merchants, Swap Dealers, and Major Swap Participants; Amendments to Filing Dates | |
81 FR 80716 - Advisory Board; Notice of Meeting | |
81 FR 80610 - Fisheries of the Exclusive Economic Zone Off Alaska; Pacific Cod in the Bering Sea and Aleutian Islands Management Area | |
81 FR 80713 - National Railroad Passenger Corporation's (Amtrak) Request for Positive Train Control Safety Plan (PTCSP) Approval and System Certification | |
81 FR 80714 - Proposed Agency Information Collection Activities; Comment Request | |
81 FR 80640 - Certain Small Diameter Carbon and Alloy Seamless Standard, Line, and Pressure Pipe (Under 41/2 | |
81 FR 80635 - Certain Large Diameter Carbon and Alloy Seamless Standard, Line, and Pressure Pipe (Over 41/2 | |
81 FR 80638 - Carbon and Certain Alloy Steel Wire Rod From Mexico: Preliminary Results of Antidumping Duty Administrative Review; 2014-2015 | |
81 FR 80587 - Section 707 Regarding Disguised Sales, Generally; Correction | |
81 FR 80687 - Advisory Committee for Computer and Information Science and Engineering; Notice of Meeting | |
81 FR 80652 - Orders Granting Authority To Import and Export Natural Gas, To Import and Export Liquefied Natural Gas, and Vacating Prior Authority During September 2016 | |
81 FR 80653 - Proposed Subsequent Arrangement | |
81 FR 80650 - Judicial Proceedings Since Fiscal Year 2012 Amendments Panel (Judicial Proceedings Panel); Notice of Federal Advisory Committee Meeting | |
81 FR 80710 - Application From the State of Utah to the Surface Transportation Project Delivery Program and Proposed Memorandum of Understanding (MOU) Assigning Environmental Responsibilities to the State | |
81 FR 80631 - Nutrition Facts Label Compliance | |
81 FR 80687 - Research Performance Progress Report | |
81 FR 80712 - FAST Act Section 1422 Study on Performance of Bridges | |
81 FR 80708 - Renewal Package From the State of California to the Surface Transportation Project Delivery Program and Proposed Memorandum of Understanding (MOU) Assigning Environmental Responsibilities to the State | |
81 FR 80679 - Information Collection Activities: Sulfur Operations; Submitted for Office of Management and Budget (OMB) Review; Comment Request | |
81 FR 80633 - Submission for OMB Review; Comment Request | |
81 FR 80649 - North Pacific Fishery Management Council; Public Meeting | |
81 FR 80621 - Safety Zone; Vigor Industrial Drydock Movement, West Duwamish Waterway; Seattle, WA | |
81 FR 80664 - Office of Public Health Preparedness and Response (OPHPR) Board of Scientific Counselors, Office of Public Health Preparedness and Response, (BSC, OPHPR) | |
81 FR 80665 - Advisory Council for the Elimination of Tuberculosis Meeting (ACET) | |
81 FR 80651 - Agency Information Collection Activities; Submission to the Office of Management and Budget for Review and Approval; Comment Request; Common Core of Data (CCD) School-Level Finance Survey (SLFS) 2016-2018 | |
81 FR 80719 - Submission for OMB Review; Comment Request | |
81 FR 80720 - Agency Information Collection Activity Under OMB Review: (Ischemic Heart Disease (IHD) Disability Benefits Questionnaire (VA Form 21-0960A-1), Hairy Cell and Other B-Cell Leukemia Disability Benefits Questionnaire (VA Form 21-0960B-1), and Parkinson's Disease Disability Benefits Questionnaire (VA Form 21-0960C-1)) | |
81 FR 80655 - Tesoro Great Plains Gathering & Marketing LLC; Notice of Request for Temporary Waiver | |
81 FR 80655 - Combined Notice of Filings #2 | |
81 FR 80660 - Combined Notice of Filings #1 | |
81 FR 80654 - Combined Notice of Filings | |
81 FR 80656 - Combined Notice of Filings | |
81 FR 80657 - SR South Loving LLC; Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization | |
81 FR 80660 - Central Hudson Gas & Electric Corporation; Tucson Electric Power Company; UNS Electric, Inc.; UniSource Energy Development Company; Notice of Institution of Section 206 Proceeding and Refund Effective Date | |
81 FR 80659 - Combined Notice of Filings #1 | |
81 FR 80594 - Medicare and Medicaid Programs; Emergency Preparedness Requirements for Medicare and Medicaid Participating Providers and Suppliers; Correction | |
81 FR 80683 - Welded Stainless Steel Pressure Pipe From India | |
81 FR 80637 - Export Trade Certificate of Review | |
81 FR 80643 - Atlantic Highly Migratory Species; Meeting of the Atlantic Highly Migratory Species Advisory Panel | |
81 FR 80701 - Self-Regulatory Organizations; The NASDAQ Stock Market LLC; Notice of Filing and Immediate Effectiveness of Proposed Rule Change To Amend the NBBO Program | |
81 FR 80689 - Self-Regulatory Organizations; Chicago Board Options Exchange, Incorporated; Notice of Filing and Immediate Effectiveness of a Proposed Rule Change To Amend the Fees Schedule | |
81 FR 80703 - Self-Regulatory Organizations; NYSE Arca, Inc.; Notice of Filing and Immediate Effectiveness of Proposed Rule Change To Temporarily Widen Price Collar Thresholds for the Core Open Auction and Trading Halt Auctions | |
81 FR 80694 - Self-Regulatory Organizations; NASDAQ PHLX LLC; Notice of Filing of Partial Amendment No. 2 and Order Granting Approval of a Proposed Rule Change, as Modified by Partial Amendment No. 2, To Amend PHLX Rule 1017, Openings in Options | |
81 FR 80705 - Self-Regulatory Organizations; Bats EDGX Exchange, Inc.; Notice of Filing and Immediate Effectiveness of a Proposed Rule Change to Fees for Use of the Exchange's Equity Options Platform | |
81 FR 80691 - Self-Regulatory Organizations; Miami International Securities Exchange LLC; Notice of Filing and Immediate Effectiveness of a Proposed Rule Change To Amend Exchange Rule 519A, Risk Protection Monitor | |
81 FR 80646 - Atlantic Highly Migratory Species; Exempted Fishing, Scientific Research, Display, Shark Research Fishery, and Chartering Permits; Letters of Acknowledgment | |
81 FR 80645 - Proposed Information Collection; Comment Request; Large Pelagic Fishing Survey | |
81 FR 80644 - Taking and Importing Marine Mammals; Taking Marine Mammals Incidental to the Elliot Bay Seawall Project in Seattle, Washington | |
81 FR 80667 - Office of the Director, National Institutes of Health; Notice of Meeting | |
81 FR 80668 - National Institute of Dental & Craniofacial Research; Notice of Closed Meeting | |
81 FR 80668 - Center for Scientific Review; Notice of Closed Meeting | |
81 FR 80667 - Center for Scientific Review; Notice of Closed Meetings | |
81 FR 80684 - Commerce in Explosives; 2016 Annual List of Explosive Materials | |
81 FR 80721 - Veterans' Advisory Committee on Rehabilitation; Notice of Meeting | |
81 FR 80567 - Refuse To Accept Procedures for Premarket Tobacco Product Submissions; Withdrawal | |
81 FR 80665 - Agency Information Collection Activities: Submission for OMB Review; Comment Request | |
81 FR 80666 - Site Visit Training Program for Office of Pharmaceutical Quality Staff; Information Available to Industry | |
81 FR 80656 - Essential Power Massachusetts, LLC; Nautilus Hydro, LLC; Notice of Application for Transfer of License and Soliciting Comments, Motions To Intervene, and Protests | |
81 FR 80656 - South Carolina Public Service Authority; Notice of Application Accepted for Filing and Soliciting Comments, Motions To Intervene, and Protests | |
81 FR 80658 - Texas Eastern Transmission, LP; Notice of Application | |
81 FR 80654 - PennEast Pipeline Company, LLC; Notice of Revised Schedule for Environmental Review of the PennEast Pipeline Project | |
81 FR 80654 - Kinetica Energy Express, LLC; Notice of Technical Conference | |
81 FR 80662 - Kaukauna Utilities; Notice of Intent To File License Application, Filing of Pre-Application Document, and Approving Use of the Traditional Licensing Process | |
81 FR 80682 - Recent Trends in U.S. Services Trade, 2017 Annual Report | |
81 FR 80689 - New Postal Product | |
81 FR 80618 - Proposed Establishment of Class E Airspace; Wessington Springs, SD | |
81 FR 80620 - Proposed Establishment of Class E Airspace, Denver, CO | |
81 FR 80587 - Oil and Gas and Sulfur Operations in the Outer Continental Shelf-Decommissioning Costs for Pipelines | |
81 FR 80612 - Safeguarding of Restricted Data by Access Permittees | |
81 FR 80629 - Protective Regulations for Hawaiian Spinner Dolphins Under the Marine Mammal Protection Act; Reopening of Public Comment Period | |
81 FR 80567 - Establishing a More Effective Fair Market Rent System; Using Small Area Fair Market Rents in the Housing Choice Voucher Program Instead of the Current 50th Percentile FMRs | |
81 FR 80678 - Small Area Fair Market Rents in Housing Choice Voucher Program Values for Selection Criteria and Metropolitan Areas Subject to Small Area Fair Market Rents | |
81 FR 80724 - Violence Against Women Reauthorization Act of 2013: Implementation in HUD Housing Programs | |
81 FR 80828 - Renewables Enhancement and Growth Support Rule | |
81 FR 80594 - Telephone Consumer Protection Act of 1991 |
Food Safety and Inspection Service
Census Bureau
Foreign-Trade Zones Board
International Trade Administration
National Oceanic and Atmospheric Administration
Federal Energy Regulatory Commission
Centers for Disease Control and Prevention
Centers for Medicare & Medicaid Services
Food and Drug Administration
National Institutes of Health
Coast Guard
Federal Emergency Management Agency
Bureau of Safety and Environmental Enforcement
Surface Mining Reclamation and Enforcement Office
Alcohol, Tobacco, Firearms, and Explosives Bureau
Federal Aviation Administration
Federal Highway Administration
Federal Railroad Administration
Saint Lawrence Seaway Development Corporation
Comptroller of the Currency
Internal Revenue Service
United States Mint
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Commodity Futures Trading Commission.
Final rule.
The Commodity Futures Trading Commission (“Commission” or “CFTC”) is amending its regulations regarding the timing for furnishing to the Commission the chief compliance officer (“CCO”) annual reports of futures commission merchants (“FCMs”), swap dealers (“SDs”), and major swap participants (“MSPs”) (collectively, “Registrants”). The Commission is also amending its regulations by delegating to the Director of the Division of Swap Dealer and Intermediary Oversight (“DSIO”) authority to grant extensions to the CCO annual report filing deadline.
This rule will become effective November 16, 2016.
Eileen T. Flaherty, Director, 202-418-5326,
On August 12, 2016, the Commission published a Notice of Proposed Rulemaking (“Proposal”)
The Commission generally requested comments on the Proposal and also solicited comments on certain specific matters.
In response to the Proposal, the Commission received one comment submitted jointly by the Futures Industry Association (the “FIA”), International Swaps and Derivatives Association (“ISDA”), and the Securities Industry and Financial Markets Association (“SIFMA”) (collectively, “Commenters”) on behalf of their FCM, SD, and MSP member firms.
The Commenters made several suggestions aimed at more closely aligning the Proposal with the relief provided in CFTC Staff Letter No. 15-15 and providing greater certainty for all SDs. First, Commenters cautioned against linking the filing deadline for the CCO Annual Report to the submission date for the applicable annual financial reports. The Commenters stated that using the
The Commenters further noted that under the Commission's proposed Capital Requirements of Swap Dealers and Major Swap Participants rulemaking,
Finally, regarding application of the Proposal to Substituted Compliance Registrants, the Commenters requested that the Commission provide “supplemental guidance as to what constitutes a `specifically identifiable completion date'” for Substituted Compliance Registrants who file comparable annual reporting information (hereinafter, “Comparable Annual Report”).
The Commission has considered the comments it received in response to the Proposal. Upon consideration of Commenters' suggestions, the Commission's implementation experience,
The Commission believes that the language in CEA section 4s(k)(3)(B) requiring the CCO to “annually” prepare a compliance report to accompany each “appropriate” financial report does not require a simultaneous filing of the two reports to achieve its intended purpose. Rather, the intention of the statute is to require the CCO Annual Report to follow an annual reporting cycle in line with the financial reporting cycle aimed at providing the Commission, and a Registrant's senior management, with a timely self-evaluation and internal assessment of the Registrant's compliance program.
Permitting all Registrants to submit their CCO Annual Report to the Commission within 90 days after their fiscal year-end meets the statutory intent of having the CCO Annual Report follow an annual reporting cycle in line with the financial reporting cycle while providing fair and consistent treatment across all Registrants. The final rule also ensures that Registrants may continue to leverage their existing report preparation processes that were developed while the Commission's no-action relief was in place. This ensures that there is effectively no change in the burden and expense of preparing the CCO Annual Reports as a result of the final rule.
With respect to the application of new paragraph (f)(2)(ii) to Substituted Compliance Registrants, the Proposal provided that Substituted Compliance Registrants whose home jurisdictions' regulations identify a specific completion or due date have 15 days after that date to submit their Comparable Annual Report to the CFTC. If a Substituted Compliance Registrant's home jurisdiction does not require or is silent as to a particular completion or due date for the Comparable Annual Report, then the Substituted Compliance Registrant must furnish its Comparable Annual Report to the Commission not more than 90 days after its fiscal year-end.
As described above, the Commenters requested additional guidance on the meaning of “specifically identifiable completion date.” The Commission is clarifying that the completion or due date could be set by the Substituted Compliance Registrant's home
The Commission, however, is concerned about the possibility of significant reporting delays or deferrals that may apply to a specific Registrant. Accordingly, the Commission expects that a Substituted Compliance Registrant will inform the Commission of any delays or deferrals beyond the deadlines set by their home jurisdiction regulations or applicable regulatory authority that would extend that particular Registrant's Comparable Annual Report filing date, and seek appropriate relief under Regulation 3.3(f)(5), as necessary.
The Commission received no comments on its proposal to delegate to the Director of DSIO, or such other employee(s) that the Director may designate, the authority to grant extensions of time to file CCO Annual Reports. Accordingly, the Commission is adopting new paragraph (h) as proposed.
The Regulatory Flexibility Act
As discussed in the Proposal, the final rule amends the filing deadline for CCO Annual Reports of FCMs, SDs, and MSPs and clarifies the filing deadline for Comparable Annual Reports. The final rule affects FCMs, SDs, and MSPs that are required to be registered with the Commission. The Commission has previously established certain definitions of “small entities” to be used in evaluating the impact of its regulations on small entities in accordance with the RFA, and has previously determined that FCMs, SDs, and MSPs are not small entities for purposes of the RFA.
The Paperwork Reduction Act of 1995 (“PRA”)
As discussed above, the Commission is adopting amendments to the filing requirements for CCO Annual Reports in Regulation 3.3 that: (1) Increase the amount of time registrants have to file their CCO Annual Reports with the Commission; and (2) clarify the filing requirements for Comparable Annual Reports. The baseline for this cost and benefit consideration is existing Commission Regulation 3.3.
The final rule does not change the report contents or require any additional actions to be taken by Registrants. The 90 days (or up to 15 days after the date on which a Comparable Annual Report must be completed under applicable home jurisdiction standards that allow more time) provided by the final rule lengthens the time before senior management or the board of the Registrants and the Commission may receive the CCO Annual Reports. The additional time to furnish the reports should not materially impact regulatory oversight given that the purpose of the reports is to provide a status update for the Registrant's compliance activities over the course of the preceding fiscal year and planned changes for the coming year. The reports generally do not serve to address crisis situations for which immediacy is critical. Therefore, the additional time allowed should not materially impact the usefulness of the information in the reports.
The Commission believes that the final rule provides relief for Registrants
Section 15(a) of the CEA requires the Commission to consider the costs and benefits of its actions before promulgating a regulation under the CEA or issuing certain orders.
The Commission recognizes that there are trade-offs between reducing regulatory burdens and ensuring that the Commission has sufficient, timely information to fulfill its regulatory mission. The final rule is intended to reduce some of the regulatory burdens on Registrants. While the final rule will delay the time in which the Commission will receive the CCO Annual Reports, the delay is relatively short given that the information in the reports looks back over the entire year-long reporting period, and identifies planned improvements for the coming year. Accordingly, the Commission believes that the short delay will not affect the protection of market participants and the public.
The Commission believes that the final rule could improve allocational efficiency for participants in the market by reducing the burden of preparing the CCO Annual Report in a shorter time-frame thereby allowing them to allocate compliance resources more efficiently over the report preparation period. The Commission believes that the final rule will not have any market efficiency, competitiveness, or market integrity impacts because the reports address internal compliance programs of each Registrant and are not publicly available.
The Commission believes that the final rule does not impact on price discovery. Given that the final rule affects only the timing of when the CCO Annual Reports are filed with the Commission and the CCO Annual Reports generally would not contain trade information or be available to the public, the final rule does not affect price discovery.
The Commission believes that the final rule will not have a meaningful effect on the risk management practices of Registrants. While the CCO Annual Reports may discuss certain risk management aspects related to Registrants' compliance programs, the final rule only amends the timing of delivery of the reports to the Commission, not the contents of the reports. As described above under subsection 4.a, the short delay in delivery of the reports provided for by the final rule is not significant given the nature of the information included in the report and allowing additional time to prepare CCO Annual Reports might allow Registrants to prepare better reports that more effectively address the information contained therein.
The Commission has not identified any other public interest considerations for this rulemaking.
Administrative practice and procedure, Brokers, Commodity futures, Major swap participants, Reporting and recordkeeping requirements, Swap dealers.
For the reasons stated in the preamble, the Commodity Futures Trading Commission amends 17 CFR part 3 as follows:
5 U.S.C. 552, 552b; 7 U.S.C. 1a, 2, 6a, 6b, 6b-1, 6c, 6d, 6e, 6f, 6g, 6h, 6
The revision and addition read as follows:
(f) * * *
(2)(i) Except as provided in paragraph (f)(2)(ii) of this section, the annual report shall be furnished electronically to the Commission not more than 90 days after the end of the fiscal year of the futures commission merchant, swap dealer, or major swap participant.
(ii) The annual report of a swap dealer or major swap participant that is eligible to comply with a substituted compliance regime for paragraph (e) of this section pursuant to a comparability determination of the Commission may be furnished to the Commission electronically up to 15 days after the date on which the comparable annual report must be completed under the requirements of the applicable substituted compliance regime. If the substituted compliance regime does not specify a date by which the comparable annual report must be completed, then the annual report shall be furnished to the Commission by the date specified in paragraph (f)(2)(i) of this section.
(h)
The following appendix will not appear in the Code of Federal Regulations.
On this matter, Chairman Massad and Commissioners Bowen and Giancarlo voted in the affirmative. No Commissioner voted in the negative.
Food and Drug Administration, HHS.
Direct final rule; withdrawal.
The Food and Drug Administration (FDA) published in the
The direct final rule published at 81 FR 52329 (August 8, 2016), is withdrawn effective November 16, 2016.
Annette Marthaler or Paul Hart, Office of Regulations, Center for Tobacco Products, Food and Drug Administration, Document Control Center, Bldg. 71, Rm. G335, 10903 New Hampshire Ave., Silver Spring, MD 20993-0002, 877-287-1373,
Therefore, under the Federal Food, Drug, and Cosmetic Act, and under authority delegated to the Commissioner of Food and Drugs, the direct final rule published on August 8, 2016, (81 FR 52329) is withdrawn.
Office of the Secretary, HUD.
Final rule.
This final rule applies the use of Small Area Fair Market Rents (Small Area FMRs) in the administration of the Housing Choice Voucher (HCV) program for certain metropolitan areas. This final rule provides for the use of Small Area FMRs, in place of the 50th percentile rent, the currently codified regulations, to address high levels of voucher concentration in certain communities. The use of Small Area FMRs is expected to give HCV tenants access to areas of high opportunity and lower poverty areas by providing a subsidy that is adequate to cover rents in those areas, thereby reducing the number of voucher families that reside in areas of high poverty concentration.
For information about this rule, contact Peter B. Kahn, Director, Economic and Market Analysis Division, Office of Economic Affairs, Office of Policy Development and Research, U.S. Department of Housing and Urban Development, 451 7th Street SW., Washington, DC 20410, telephone (202) 402-2409 or Becky L. Primeaux, Director, Housing Voucher Management and Operations Division, U.S. Department of Housing and Urban Development, 451 7th Street SW., Washington, DC 20410, telephone (202) 708-0477; email:
Under this final rule, public housing agencies (PHAs) operating in designated metropolitan areas are required to use Small Area FMRs, while PHAs not operating in the designated areas have the option to use Small Area FMRs in administering their HCV programs. Other programs that use FMRs would continue to use area-wide FMRs. This final rule also provides for regulatory implementation of certain provisions of the Housing Opportunity Through Modernization Act (HOTMA) related to FMRs, as well as conforming regulatory changes to part 982 concerning the reduction in payment standards during the term of the Housing Assistance Payment (HAP) contract in the HCV program. Specifically, the final rule provides for publication of FMRs by way of the World Wide Web, and provides that PHAs are no longer required to reduce the payment standard for a family under HAP contract when the PHA is required to reduce the payment standard for its program as the result of a reduction in the FMR.
This final rule establishes a more effective means for HCV tenants to move into areas of higher opportunity and lower poverty by providing the tenants with a subsidy adequate to make such areas accessible and, consequently, help reduce the number of voucher families that reside in areas of high poverty concentration. Prior to this rule, subsidy for HUD's HCV program is determined by a formula that considers rent prices across an entire metropolitan area. However, rents can vary widely within a metropolitan area depending upon the size of the metropolitan area and the neighborhood in the metropolitan area within which one resides. The result of determining rents on the basis of an entire metropolitan area is that a voucher subsidy may be too high or may be too low to cover market rent in a given neighborhood. To date, HUD's policy for addressing high concentrations of voucher holders raises the level of the FMR from the 40th percentile to the 50th percentile (roughly a 7—8 percent increase) in the whole FMR area. This level of added subsidy has not been targeted to areas of opportunity, and consequently, this formula has not proven effective in addressing the problem of concentrated poverty and economic and racial segregation in neighborhoods. Experience with the 50th percentile regime has shown that the majority of HCV tenants use their vouchers in neighborhoods where rents are low but
This rule provides that in lieu of determining rents on the basis of an entire metropolitan area, rents will be determined on the basis of ZIP codes for those metropolitan areas with both significant voucher concentration challenges and market conditions where establishing FMRs by ZIP code areas has the potential to significantly increase opportunities for voucher families. ZIP codes are small enough to reflect neighborhood differences and provide an easier method of comparing rents within one ZIP code to another ZIP code area within a metropolitan area. Based on early evidence from PHAs using Small Area FMRs that are in place in certain metropolitan areas in the U.S., HUD believes that Small Area FMRs are more effective in helping families move to areas of higher opportunity and lower poverty.
The major provisions of this final rule are set out in two sections: (1) Those that were in the proposed rule and retained at the final rule; and (2) those that were revised at the final rule or are new provisions at the final rule stage, developed in response to public comment: The major provisions are as follows:
• Defines Small Area FMR areas as the U.S. Postal Service ZIP code areas within a designated metropolitan area.
• Provides for criteria by which Small Area FMRs will be set. Small Area FMRs will be set for metropolitan areas where the area includes the following criteria: number of HCVs under lease (initially, 2,500 or more); the standard quality rental stock, within the metropolitan area, that is in small areas (that is ZIP codes) where the Small Area FMR is more than 110 percent of the metropolitan FMR (initially 20 percent or more); and the percentage of voucher holders living in concentrated low-income areas relative to all renters within these areas over the entire metropolitan area exceeds a specified threshold (initially 1.55). (This final rule also adopts additional criteria for setting Small Area FMRs for a metropolitan area, see below.)
• Defines “concentrated low-income areas” to mean those census tracts in the metropolitan FMR area with a poverty rate of 25 percent or more; or any tract in the metropolitan FMR area where 50 percent or more of the households earn incomes at less than 60 percent of the area median income (AMI) and are designated as Qualified Census Tracts in accordance with section 42 of the Internal Revenue Code (26 U.S.C. 42).
• Provides for designation of Small Area FMR areas at the beginning of a Federal fiscal year and makes additional area designations every 5 years thereafter as new data becomes available.
• Requires if a metropolitan area meets the criteria for application of Small Area FMRs, that all PHAs administering HCV programs in that area will be required to use Small Area FMRs.
• Provides that a PHA that is administering an HCV program in a metropolitan area that is not subject to application of Small Area FMRs may opt to use Small Area FMRs by seeking approval of HUD's Office of Public and Indian Housing through written request to such office.
• For all rent determinations of FMRs, 40th percentile or Small Area FMRs, replaces “the most recent decennial census” with the “most recent American Community Survey conducted by the U.S. Census Bureau.”
• Provides that metropolitan areas with FMRs set at the 50th percentile rent will transition to either (1) the 40th percentile rent at the expiration of the 3-year period for the 50th percentile rent, or (2) designation as a Small Area FMR area in accordance with the criteria for determining a Small Area FMR area.
• Provides that a PHA with jurisdiction in a 50th percentile FMR area that reverts to the standard 40th percentile FMR may request HUD approval of payment standard amounts based on the 50th percentile rent in accordance with the regulations in 24 CFR 982.503(f) that are changed by this final rule. PHAs, however, would be required to continue to meet the provisions of 24 CFR 982.503(f) annually in order to maintain payment standards based on 50th percentile rents.
• Removes the existing regulations at 24 CFR 888.113 that provide for FMRs to be set at the 50th percentile rent. However, for areas not selected for implementation of Small Area FMRs, the final rule does not revoke any FMR currently set at the 50th percentile rent, and for which the current 3-year term for retaining a 50th percentile rent has not expired.
• Conforms the regulations at § 982.505(c)(3) with the portion of section 107 of the Housing Through Opportunity Modernization Act (HOTMA), Public Law 114-201, which provides PHAs with the option to hold families under a Housing Assistance Payments (HAP) contract harmless from payment standard reductions that are currently required at the family's second annual recertification if the family's payment standard falls outside of the basic range as the result of a decrease in FMRs (including a decrease in FMR attributable to the implementation of Small Area FMRs). As an additional protection, the final rule provides that should a PHA choose not to hold the payment standard at its current level for families under HAP contract in an area experiencing a payment standard reduction, the PHA may set the payment standard for families that remain under HAP contract at any amount between the current payment standard and new normally applicable payment standard amount, and may further reduce the payment standard for families under HAP contract over time to gradually bring the family's payment standard down to payment standard that is normally applicable to the area for the PHA's program or reduce the gap between the two payment standards. The rule further extends these same flexibilities to the PHA in cases where the payment standard decrease is not the result of a FMR decrease.
The rule further provides that if the PHA chooses to apply a reduction in the payment standard to the family's subsidy calculation during the HAP contract term, the earliest the PHA may implement the initial reduction in the payment standard is the second regular reexamination following the effective date of the decrease in the payment standard amount. Section 107 of HOTMA also provides new requirements for publishing HUD's FMRs.
• Additional criteria by which Small Area FMRs will be set.
○ Adds the vacancy rate of an area as a criterion to the selection parameters for Small Area FMRs. The vacancy rate will be calculated in the following manner: Using data from the 1-year American Community Survey (ACS) tabulations, the vacancy rate is the number of Vacant For Rent Units divided by the sum of the number of Vacant For Rent Units, the number of Renter Occupied Units, and the number
○ Adds an additional requirement to the voucher concentration ratio included in the proposed rule. In addition to requiring the ratio of the proportion of voucher tenants in concentrated low-income areas (CLIAs) to the proportion of renter occupied units in CLIAs to exceed a minimum threshold (initially 155 percent), the final rule requires that the numerator of the ratio (the proportion of voucher tenants in CLIAs) meet or exceed a minimum threshold. Initially, this threshold will be set at 25 percent.
• Exempts all project-based vouchers from required application of Small Area FMRs but allows a PHA operating under the Small Area FMRs for its tenant-based program to apply Small Area FMRs to future PBV projects (and to current PBV projects provided the owner mutually agrees to the change).
• Provides that a PHA's selection to use Small Area FMRs for PBVs would not require HUD approval but should be undertaken in accordance with guidance issued by HUD and indicated in the PHA's administrative plan.
• Rather than codify both the selection criteria and the selection values in the regulatory text as in the proposed rule, the final rule codifies the selection criteria in the regulatory text, but does not codify the selection values in the regulatory text. The selection values for the first round of Small Area FMR areas is announced in a separate notice published in today's
• Makes two changes to the exception payment standard requirements in response to public comments:
○ PHAs not operating in Small Area FMR designated areas may establish exception payment standards for a ZIP code area of up to 110 percent of the relevant Small Area FMR by notifying HUD; and
○ The 50 percent population cap (24 CFR 982.503(c)(5)) will not be applicable to Exception Payment Standards in Small Area FMR areas.
• Exempts manufactured home space rental from Small Area FMRs.
• Provides that PHAs have up to three months from the date when the new FMRs go into effect in which to update their payment standards if a change is necessary to fall within the basic range of new FMRs. For example, if the new FMR went into effect on October 1, 2017, the PHA would need to update their payment standard if necessary to fall within the basic range of the new FMRs no later than January 1, 2018.
• Provides HUD may suspend a Small Area FMR designation for a metropolitan area, including at the request of a PHA, where HUD determines such action is warranted based on a documented finding of adverse rental housing market conditions that will be set out by notice (for example, the metropolitan area experiences a significant loss of housing units as a result of a natural disaster).
• Provides that HUD may provide an exception payment standard for a PHA administering the HCV program under Small Area FMRs for an entire ZIP Code area in accordance with the conditions and procedures provided by notice in the
The main benefit of the final rule is that, through setting rental subsidy amounts at a more local level, assisted households will be more able to afford homes in areas of high opportunity than under current policy. Such moves are expected to benefit both individual households, for example, through access to better schools or safer neighborhoods, and areas as a whole through reducing concentrated neighborhood poverty. Other benefits could arise through the reduction of overpayment of rent in areas where the neighborhood rent is below the metropolitan average. Early evidence from current Small Area FMR locations suggests that there could be per-voucher cost decreases relative to 50th percentile rents, depending on the choices made by tenants. Evidence also suggests that families moved to better neighborhoods with higher rents, although not greatly in excess of the metropolitan FMR, which resulted in no overall program cost increases.
Potential costs of the final rule include the administrative expenses associated with implementation on the part of PHAs. Additionally, if there are barriers to households moving to areas of higher opportunity beyond housing costs, such as transportation expenses or social factors, assisted households might be worse off if they can no longer afford their current units in their neighborhoods. This may be particularly true for elderly families or families with a disabled member; however, HUD regulations allow PHAs wide latitude in setting payments standards for disabled tenants as “reasonable accommodations” of their disabilities. Finally, if the long-term impacts of the final rule cause per-voucher costs to rise, fewer households would receive assistance without an overall increase in program funds.
HUD's HCV program helps low-income households obtain standard rental housing and reduces the share of their income that goes toward rent. Vouchers issued under the HCV program provide subsidies that allow individuals and families to rent eligible units in the private market. A key parameter in operating the HCV program is the FMR. In general, the FMR for an area is the amount that would be needed to pay the gross rent (shelter rent plus utilities) of privately owned, decent, and safe rental housing of a modest (non-luxury) nature with suitable amenities. In addition, all rents subsidized under the HCV program must meet rent reasonableness standards. Rent reasonableness is determined by PHAs with reference to rents for comparable unassisted units.
In the HCV program, the FMR is the basis for determining the “payment standard amount” used to calculate the maximum monthly subsidy for a voucher household (see § 982.503). PHAs may establish payment standards between 90 and 110 percent of the FMR.
HUD establishes FMRs for different geographic areas. Because payment standards are based on FMRs, housing assistance payments on behalf of the voucher household are limited by the geographic area in which the voucher household resides. HUD calculates FMRs for all nonmetropolitan counties and metropolitan areas. To date, the same FMR is applicable throughout a nonmetropolitan county or metropolitan area, which generally is comprised of several metropolitan counties. FMRs in a metropolitan area (Metropolitan FMR) represent the 40th percentile (or in special circumstances the 50th percentile) gross rent for typical non-luxury, non-substandard rental units occupied by recent movers in a local housing market.
As noted earlier, HUD regulations have allowed a PHA to set a payment standard between 90 percent and 110 percent (inclusive) of the FMR. PHAs may determine that payment standards that are higher than 110 percent, or lower than 90 percent, are appropriate for subareas of their market; in this instance, a PHA would request HUD approval for a payment standard below 90 percent or an exception payment standard above 110 percent. The total population of a HUD-approved exception payment area (
On October 2, 2000, at 65 FR 58870, HUD published a rule (2000 rule) establishing policy, currently in HUD's codified regulations, to set FMRs at the 50th percentile for “areas where higher FMRs are needed to help families, assisted under HUD's program as well as other HUD programs, find and lease decent and affordable housing.” This policy was put in place to achieve two program objectives: (1) Increase the ability of low-income families to find and lease decent and affordable housing; and (2) provide low-income families with access to a broad range of housing opportunities throughout a metropolitan area. The policy further provides that PHAs that had been authorized to use FMRs set at the 50th percentile rent may later be required to use FMRs set at the 40th percentile rent. This would occur if the FMR were set at the 50th percentile rent to provide a broad range of housing opportunities throughout a metropolitan area for three years, but the concentration of voucher holders in the metropolitan area did not lessen.
Since HUD established the 50th percentile FMRs 16 years ago, research has emerged
Since the establishment of the 50th percentile program, HUD has developed Small Area FMRs to reflect rents in ZIP code based areas with a goal to improve HCV tenant outcomes. Small Area FMRs have been shown to be a more direct approach to encouraging tenant moves to housing in lower poverty areas by increasing the subsidy available in specific ZIP codes to support such moves.
Toward this end, through a
Through a second
On June 2, 2015, at 80 FR 31332, HUD published an advance notice of proposed rulemaking (ANPR) entitled “Establishing a More Effective Fair Market Rent (FMR) System; Using Small Area Fair Market Rents (Small Area FMRs) in Housing Choice Voucher Program Instead of the Current 50th Percentile FMRs.” In this ANPR, HUD announced its intention to amend HUD's FMR regulations applicable to the HCV program to provide HCV tenants with subsidies that better reflect the localized rental market, including subsidies that would be relatively higher if they move into areas that potentially have better access to jobs, transportation, services, and educational opportunities. The ANPR sought public
On June 16, 2016, at 81 FR 39218, HUD published a proposed rule that require the use of Small Area FMRs in place of the 50th percentile rent to address high levels of voucher concentration. The proposed rule addressed the issues and suggestions raised by public commenters on the ANPR. (See 81 FR 39222 through 39224.) In addition to responding to public comments on the ANPR, HUD specifically requested comment on certain issues. (See 81 FR 39224 through 39226.) HUD received 113 comments on its June 16, 2016, proposed rule. The public comments can be found at
The significant issues raised by the public commenters and HUD's responses are provided in the following section of this preamble.
Commenters were divided in their support for the rule. For those commenters that supported the rule they stated that this new methodology was long overdue because the current system was not working. Commenters stated that the current system was not working and HUD's proposal sounded like a good solution. Commenters stated that creating a system where cities, counties and municipalities could have a finer laser point on their rental markets could increase subsidy utilization rates and customer choice. The commenters stated that they highly recommended not only looking at the proposed methodologies but also collecting and refining more data from cities on their housing stock and availability. A commenter stated that setting FMRs for smaller areas is an ingenious solution because it will put an end to unnecessarily high subsidies in high poverty areas, and will gradually erode the legacy of segregation by giving HCV households more access to low-poverty neighborhoods. Another commenter stated that this FMR change is a welcome innovative step toward increasing housing choices for low-income individuals and families. Other commenters stated that the goal of the Small Area FMR rule will benefit people with disabilities by affording them better opportunities for integration into the community.
For those commenters that opposed the rule they offered the following concerns. A commenter stated HUD's proposal would result in Section 8 recipients in designated ZIP codes experiencing decreases in their subsidies, and these recipients would be obliged to increase their out-of-pocket share. Other commenters stated that research indicates low poverty rates are not 100 percent indicative of high opportunity areas. The commenters stated that given this information, Small Area FMRs are not an indicator of areas of opportunity and cannot be substituted for more robust mobility efforts resulting in poverty deconcentration, racial/ethnic deconcentration, and other positive outcomes associated with areas of opportunity. Other commenters similarly stated that voucher holders access to opportunity/higher market neighborhoods is only partially impacted by adequate payment standards. The commenters stated that while higher payment standards are essential this is not a solution to moving low-income families with children into opportunity neighborhoods. Commenters stated that HUD should not implement Small Area FMRs unless HUD revises the HCV funding formula to ensure that implementation of the rule does not result in fewer households being subsidized under the voucher program.
The following presents the specific issues that commenters raised on the proposed rule and HUD's responses.
In the proposed rule, HUD sought comment on 13 specific areas presented below.
1. Should HUD provide for PBVs that are in the pipeline to continue using metropolitan FMRs even if the area is designated as a Small Area FMR area? Additionally, should HUD require newly proposed PBVs post Small Area FMR designation to use Small Area FMRs?
Given the range and variation among public comments, and the range of uses of PBV within HUD's rental assistance programs, HUD is choosing to exempt all current and future PBVs from Small Area FMRs at this time. However, if a PHA is operating its tenant-based program under the Small Area FMRs, the PHA may apply Small Area FMRs to all future PBV projects if it establishes such a policy in its PHA administrative plan. In such a case, the PHA may also choose to also establish a policy that allows the PHA to apply the Small Area FMRs to current PBV projects, provided the owner is willing to mutually agree to do so. The application of the Small Area FMR to the PBV project must be prospective. The PHA and the PBV project owner operating under the Small Area FMRs may not subsequently choose to revert back to the metropolitan-wide FMR, regardless of whether the PHA subsequently changes its administrative policy to no longer apply Small Area FMRs to PBV projects. HUD believes this approach offers maximum flexibility for varied circumstances and HUD will closely monitor the results of the policy including for any fair housing or civil rights concerns.
HUD is also removing the term “jurisdiction” in § 888.113(h) for consistency since HUD provides approval to a “PHA” that requests to voluntarily use Small Area FMRs under 982.113(c) as opposed to a “PHA jurisdiction”.
2. The proposed rule provides for Small Area FMR area selection parameters to be codified in regulatory text. HUD is seeking comment on whether these parameters should be codified or should be incorporated into each annual proposed FMR notice to provide HUD, PHAs, and other stakeholders with flexibility, in any given fiscal year, to offer changes to these selection parameters and have the opportunity to comment before any changes to the parameters are made.
3. Several commenters to HUD's ANPR suggested that HUD provide for tenant rent protections in ZIP codes where the Small Area FMR is below the metropolitan area and tenants choose not to move. No additional tenant protections were instituted for tenants serviced by PHAs accepting HUD's invitation to participate in the Small Area FMR demonstration nor were additional tenant protections implemented for tenants living in the Dallas, TX HUD Metropolitan Area when Small Area FMRs were implemented there. However, as part of a transition strategy between Metropolitan FMRs and Small Area FMRs, HUD seeks comment on what additional policies or requirements the final rule should include that would mitigate the impact of significant and abrupt decreases in the FMRs for certain ZIP code areas on families currently under HAP contract in those impacted areas.
In addition, the final rule provides PHAs with the option to establish a new payment standard for families under HAP contract between the full “hold harmless” option provided under HOTMA and the new payment standard based on the Small Area FMR. Under this option, the PHA would have greater flexibility than what is afforded under HOTMA (which essentially requires the PHA to either hold the in-place families completely harmless or transition them to the new payment standard). This policy would allow the PHA to still achieve some budgetary flexibility by reducing the payment standard for families under HAP at the second reexamination, while ensuring the reduction in subsidy is modest and does not place families at risk of displacement.
The rule further extends these same flexibilities to the PHA if the payment standard decrease is not the result of a decrease in the FMR.
Finally, in order to ensure that a suitable amount of units remain available during the transition to Small Area FMRs, this final rule limits the annual decrease in Small Area FMRs to no more than 10 percent of the area's FMR in the prior fiscal year. That is, the current FMR may be no less than 90 percent of the area's FMR in the previous fiscal year. In addition, the final rule provides that HUD may approve exception payment standards for PHAs administering their HCV programs under Small Area FMRs for an individual ZIP code area in accordance with conditions and procedures set forth in a separate
4. Related to question 3, HUD seeks comment on whether the final rule should limit the potential decline in the FMR for a ZIP code area resulting from the implementation of Small Area FMRs in order to ensure that sufficient housing opportunities remain available to voucher holders? If so, HUD seeks recommendations on specific policies or requirements that should be included in the final rule to achieve the desired outcome.
a. For example, an approach would be to allow the PHA to establish exception payment standards above the basic
b. With respect to protections for tenants currently under HAP contract, one possibility may be to increase the amount of time that the family is held harmless from a decrease in the payment standard. For instance, instead of the lower payment standard going into effect on the second reexamination following the effective date of the decrease in the payment standard, the final rule could provide that the lower payment standard would not go into effect for a family under HAP contract until a later re-examination (
Regarding the proposal in which PHAs could have exception payment standards above the basic range, some commenters embraced the proposal; however, others felt it would not go far enough, and only delay the onset of rent burdens. Compared to a Small Area FMR phase-in, some commenters suggested it would protect fewer families since it is likely that only some PHAs would implement the higher payment standards. Other commenters suggested HUD could permit PHAs to set payment standards for eligible voucher holders that fall anywhere between the Small Area FMR and the metro-level FMR. Commenters also suggested that HUD limit the amount the FMR or payment standard could fall below metropolitan FMRs each year. Suggestions offered by the commenters ranged from suggesting Small Area FMRs be set no lower than 90-95 percent of the metropolitan FMR, no lower than 80-90 percent the second year, and so on in 5 percent or 10 percent increments.
Some commenters supported limiting annual FMR reductions by 3 percent or 5 percent, while others suggested the decreases should occur over a 5-year instead of a 3-year period (for all areas, or for only those areas that decrease by more than 10 percent), or the total drop be no more than 5 percent. Other commenters suggested changes included removing or increasing the cap on Small Area FMR values.
Regarding the proposal to increase the amount of time that the family is held harmless from a decrease in the payment standard, some commenters suggested HUD hold the rent harmless until at least the fifth reexamination following implementation of Small Area FMRs. Other commenters stated that if HUD implements the HOTMA payment standard provision, there would be no need to implement a hold harmless provision that holds payment standards harmless in the third, fourth, or fifth reexamination.
The rule maintains that in cases where the PHA will apply a decrease in the payment standard to families during the term of the HAP contract, the earliest that the PHA may apply the initial reduction to the payment standard amount is the second regular reexamination following the effective date of the change in the payment standard amount. This provides at minimum a family with no less than the amount of time previously provided under the regulations before a reduction in the payment standard may take effect during the term of the family's HAP contract. The final rule also provides the PHA with the administrative flexibility to further reduce the payment standard for the families that remain under HAP contract if the PHA wishes to gradually reduce or eliminate the difference between the family's payment standard and the normally applicable payment standard on the PHA's payment standard schedule over time.
HUD notes that section 78001 of the Fixing America's Surface Transportation Act (or FAST Act), amended the 1937 Act to allow PHAs to undertake full income reexaminations for families with 90 percent or more of their income from fixed-income sources every three years instead of annually. HUD recognizes that implementation of this change in the frequency of reexaminations may have significant ramifications in terms of when a decrease in a payment standard could take effect during the term of the HAP contract for some families given that under this rule the decrease may not take effect until the second regulation reexamination. Rather than try to incorporate changes to the tenant protection provisions of this rule in anticipation of those potential complications, HUD will instead consider if any changes are necessary as part of the forthcoming rule-making for implementation of those FAST Act provisions.
The final rule further provides that the PHA may establish different policies regarding how decreases in payment standards will apply during the term of the HAP contract for designated areas within their jurisdiction (
Fourth, controlling for extremely large decreases in FMRs, the final rule protects families, by limiting the maximum amount the FMR may decrease year over year to 10 percent of the prior year's FMR for the area. This protection applies to all tenants—families under HAP contract, current participants that either want or are required to move to new units, and families from the waiting list who are issued vouchers to begin their initial housing search, and to metropolitan and non-metropolitan county FMRs.
Fifth, the final rule permits a PHA that is administering its HCV program under the Small Area FMRs to request and HUD to approve exception payment standards for a ZIP Code Area under the conditions and procedures set forth in a
5. The proposed rule adds a new paragraph (i) to § 888.113 to address the transition of metropolitan areas that were previously subject to 50th percentile FMRs. HUD believes that the Small Area FMR methodology will provide HCV tenants with greater access to areas of opportunity than metropolitan area wide 50th percentile FMRs. As a result, this rule proposes that a 50th percentile metropolitan area designated for Small Area FMRs would transition to Small Area FMRs on the effective date of the Small Area FMR designation. HUD is also proposing that a 50th percentile FMR area that is not designated for Small Area FMRs would remain under 50th percentile FMRs until the end of the existing 3-year period for the 50th percentile FMRs prior to reverting to the standard 40th percentile FMRs. The rule does not eliminate provisions that permit a PHA with jurisdiction in a 50th percentile FMR area that reverts to the standard 40th percentile FMR to request HUD approval of payment standard amounts based on the 50th percentile rent in accordance with the existing § 982.503(f); however, HUD is specifically seeking comment on whether this provision should be eliminated in order to phase out the use of 50th percentile rents for deconcentration purposes. HUD would also appreciate comments as to whether or not the current SEMAP deconcentration standard is appropriate as the basis for PHAs requesting HUD to approve payment standards based on 50th percentile rents under existing § 982.503(f). HUD is specifically seeking comment on these proposed polices, as well as suggestions for alternative approaches or other recommendations on how best to phase-out 50th percentile rent FMRs for impacted metropolitan areas and transition the area to either the Small Area FMRs or the standard metropolitan-wide 40th percentile FMRs.
6. HUD is specifically seeking comment on how to reduce the administrative burden on PHAs and simplify the transition to Small Area FMRs. For example, HUD is proposing to change the percentage decrease in FMRs that triggers rent reasonableness redeterminations from 5 percent to 10 percent for Small Area FMR PHAs. HUD requests comments, however, regarding whether 10 percent is the right trigger for program-wide rent reasonableness redetermination, whether HUD should limit this proposal to Small Area FMR decreases, or also change the percentage of decrease that triggers rent reasonableness for all FMRs, and whether it should revise the trigger for program-wide rent reasonableness redeterminations at all. In regards to potentially expanding the 10 percent trigger for rent reasonableness redetermination to a program-wide requirement, HUD seeks comments on the trade-offs between administrative relief and decreased program oversight on rent levels. HUD also requests comments on what other changes would reduce the potential administrative burden and complexity for PHAs impacted by the implementation of Small Area FMRs.
Aside from whether and at what level to change the trigger, some commenters recommended this be program-wide, and not just for Small Area FMRs. Commenters urged HUD to issue updated rent reasonableness guidance—including for high opportunity neighborhoods to avoid methods disallowing rents if the methods do not adequately consider location. Commenters also urged HUD to require PHAs to be transparent with the data used to perform the analysis and make it publicly available.
Other commenters urged HUD to publish new FMRs and Small Area FMRs far in advance of their effective date to avoid requiring PHAs to redo redeterminations. Commenters asked HUD to provide at least six months after publication of Small Area FMR designations before they are required to have Small Area FMR-based payment standards in place.
Some commenters raised concerns about increasing the trigger for PBV because it would trigger rent reasonable studies that result in a significant loss of income to owners of PBV contracts. The commenters stated that for properties in which this income was assumed as part of initial financing or refinancing, the property is likely to become financially unstable and unable to meet its obligations. Other commenters stated that aside from rent reasonableness, the increased administrative costs of administering Small Area FMRs come at a time when PHAs are not being paid fully to administer the HCV program.
7. HUD is currently proposing, through this rulemaking, to expand the use of Small Area FMRs within the HCV program. HUD seeks public comment as to whether or not other HUD rental assistance programs would benefit from using Small Area FMRs in their operations. For example, would the rental assistance component of the Housing Opportunities for Persons with AIDS (HOPWA) programs be a candidate for Small Area FMR treatment? Frequently, metropolitan FMRs are inadequate for HOPWA-assisted tenants to find units near health care facilities, or in neighborhoods with better job opportunities. Should the HOPWA program regulations be amended to allow participating jurisdictions the flexibility to set tenant-based assistance rents according to Small Area FMRs either in areas that would be designated Small Area FMR areas or for the HOPWA program more generally? Would other HUD programs benefit as well?
8. As currently proposed, the Small Area FMR policy would apply to all residents within a ZIP code who receive housing vouchers. HUD seeks comment on whether there are certain situations or any specific groups of voucher recipients within the general population, such as persons with disabilities or elderly voucher recipients, where an alternate policy should apply that should exempt them from having their voucher level change as a result of this policy due to specific hardships they may encounter by having to choose between staying in their current area and receiving a smaller voucher or moving to a new area for the sake of obtaining a larger voucher?
9. Are there specific groups within the general population of voucher holders for whom this policy change would be particularly burdensome? What are the ways in which this policy change could create a disproportionate burden on certain groups like elderly and disabled voucher holders?
Specifically, certain commenters stated that tenants with disabilities may not be able to find accessible units in higher rent neighborhoods and may face limited public transportation options. They may also face discrimination in these areas. Commenters stated that it is insufficient to suggest that these tenants are not at risk because they can request reasonable accommodation. The commenters stated that many people do not know enough about their rights to request the accommodation and will not be informed of them by landlords seeking higher payments. The commenters further stated that responding to requests for accommodations from a significant portion of voucher holders may be administratively burdensome for HUD. Specific recommendations from commenters focused exception payment standards (EPS) in which HUD should (1) notify all tenants who will experience a reduced payment standard of their right to a reasonable accommodation based on disability, (2) identify tenants, based on their participant file, who might be entitled to an EPS based on disability and take affirmative steps to accommodate them, and (3) publish additional guidance with the final rule that directs PHAs to allow EPS as a reasonable accommodation in any instance when a voucher family will experience a disability-related hardship as a result of being forced to pay over 30 percent of their income in rent or move.
Commenters stated that elderly tenants may also share similar challenges finding accessible units, and that stability in a neighborhood may be more of an opportunity than mobility. Commenters also suggested families with children may be adversely impacted, as having a large number of children can act as a barrier to being able to find suitable housing. Commenters stated that families report longer search times and far fewer options.
10. HUD is seeking comment on the criteria that HUD selected for determining which metropolitan areas should be impacted by the shift to a Small Area FMR instead of the current 50th percentile policy. Did HUD use the correct criteria in making these choices? What other criteria should HUD be using to select metropolitan areas that will be impacted by this rule change and why are those criteria important?
• Vacancy: Many commenters urged HUD to factor in vacancy data into the formula. Their recommendations included:
○ Excluding low vacancy markets (those with a 4 percent, 5 percent or 6 percent vacancy rates).
○ Allow PHAs with low vacancy rates to opt out of Small Area FMRs, even if they meet HUD's criteria, and require PHAs with low vacancy rates that choose to adopt Small Area FMRs to hold current tenants harmless.
○ Exempt low vacancy areas from decreases in authorized Section 8 rent levels for existing tenants; Small Area FMRs should be implemented only for new tenants (or existing tenants who move) in these areas.
• Revising the formula
○ Considering relative voucher concentration by measuring the difference—rather than the ratio—between the voucher and renter concentration shares. HUD should use the criteria that there must be at least a 15 percent difference between renter and voucher holder concentration in low-income areas.
○ Compare voucher concentration to the distribution of all housing units rather than just rental units.
○ Reduce the required proportion of rental units in areas over 110 percent of the regional FMR to 17 percent, to capture more of our most deeply segregated metro areas. An alternative approach would prioritize metropolitan areas with the highest proportion of families with young children living in concentrated poverty neighborhoods.
○ Lower this threshold for the share of rental units in ZIP codes with Small Area FMRs above 110 percent of the metro FMR at least to 15 percent.
○ Change criterion to better target metropolitan areas in which overall segregation is the highest, with less focus on concentration of voucher households in high poverty areas relative to other renters.
• Exclusions and other comments
○ Commenters also suggested that, in order not to impede PHAs whose program management has already resulted in participants living in higher opportunity/lower poverty areas, HUD should require adoption of Small Area FMRs only by those PHAs in Metro areas meeting the Small Area FMR designation criteria whose percentage of voucher holders living in concentrated low-income areas relative to all renters in concentrated low-income areas over the entire Metro FMR area exceeds 155 percent.
○ The use of Qualified Census Tracts (QCTs) in the criteria for designating Small Area FMR areas is inappropriate. In the LIHTC program, the purpose of QCTs is to increase the supply of affordable housing in these areas. It is contradictory to incentivize the construction of affordable rental units in certain areas on the one hand, and use Small Area FMRs to move residents out of those areas on the other.
○ In addition to modifying the criteria, HUD should also revise the proposed regulation to give itself flexibility to designate highly segregated areas as Small Area FMR areas if it concludes that this is needed to further fair housing.
While HUD believes the criterion should remain focused on voucher concentration rather than residential segregation, HUD also agrees with commenters that the voucher concentration criterion should be improved to better target communities where voucher concentration is most severe. Consequently, in addition to the voucher concentration ratio included in the proposed rule, the final rule also requires the numerator of this measure, the concentration of voucher holders within concentrated low income areas, to meet a minimum standard level (25 percent).
HUD notes the other suggestions made by commenters and will evaluate program effects including access to neighborhoods with better employment opportunities, better schools, lower crime rates and lower racial and ethnic isolation to inform any future expansion of the program.
11. The proposed rule makes no changes to 24 CFR 888.113(g), the FMR for Manufactured home space rental for voucher tenants that own manufactured housing units. Under this proposed rule Small Area FMRs would apply to manufactured home space rentals in areas designated for Small Area FMRs (
12. HUD has proposed to amend the Exception Payment Standard rules at 24 CFR 982.503 to account for the fact that FMR areas in Small Area FMR designated metropolitan areas will be ZIP codes. HUD is seeking public comment to determine if there are other amendments HUD should make to the Exception Payment Standard Regulations to better facilitate the approval process of Exception Payment Standards. For example, the current exception payment standard regulations require that an exception payment standard may not include more than 50 percent of the population of the FMR area. This may be an impractical requirement when determining exception payment standards within a ZIP code. Similarly, given that ZIP codes more narrowly define the FMR area, the provision within the regulation that program justification may include helping families find housing outside areas of high poverty may not be applicable even though an exception payment standard may be necessary. Therefore, HUD is soliciting feedback to ensure that the exception payment standard regulations are revised so that PHAs may use this component of the regulations to optimize the administration of their HCV programs.
Specific requests of commenters included eliminating the population cap that prevents more than 50 percent of an area to be covered by an EPS, and clarify that that exception rents may exceed 150 percent of Small Area FMR. Commenters also suggested HUD clarify how exceptions will work for Census tracts and other small geographic areas. Some commenters suggested EPS should be available up to 130 percent in the first two years of the program; others request up to 150 percent of the FMR. Another commenter stated that HUD should publish additional guidance with the final rule that directs PHAs to allow EPS as a reasonable accommodation in any instance when a voucher family will experience hardship or pay over 30 percent of their income in rent.
Commenters recommended that PHAs be able to set a payment standard up to 120 percent of the FMR without requesting HUD approval. Other suggested eliminating the distinction between exceptions above and below 120 percent of FMR, as the differences and processes are complex. If they are kept separate, commenters suggested HUD should revise the regulation for 110-120 percent to eliminate the requirements that PHAs submit information other than data on market rents or inability to secure housing and, for standards below the basic range, rent burdens. If HUD retains the requirement that increases above 120 percent prevent financial hardship, it is crucial that HUD revise the regulation or provide guidance making clear that this includes potential hardship that deters families from moving to the exception area in the first place.
As far as the process, overall, commenters requested streamlined processes, clear guidance and an expedited path for approvals that is standardized across local HUD offices and HUD headquarters. Some commenters suggested a system in which HUD's Office of Policy Development and Research obtains data from local housing authority rent reasonable databases to immediately grant exception payment standards that will support the utilization of vouchers and prevent families from falling into homelessness or remain homeless. Commenters suggested allowing exception payment standards to remain in place for a prolonged period without PHA action. HUD could review existing exception every so many years.
HUD has decided against proposing comprehensive changes to its EPS regulations at this time due to the implementation of Small Area FMRs and the potential to learn from PHA experiences with their adoption and operation. The suggestions offered through the public comment process will however be taken into consideration whenever HUD does revisit its EPS regulations.
13. HUD makes administrative data for research into HUD's programs available in a variety of ways (
• PUMS data set should include geographic identifiers for the census tract and ZIP code tabulation area, and HUD Fair Market Rent Metro Areas (HMFAs), so researchers can incorporate neighborhood information from, for example, the American Community Survey. Because HMFAs often diverge from OMBs definitions of metropolitan areas, it would also be helpful to append key HMFA-level variables (poverty rate, median gross rent, income, etc.) to the microdata.
• Number of voucher landlords and units associated with those landlords by ZIP code to which PHAs provide access to new voucher holders. This data is public, but not easily available or centralized.
• Ensure assessments of fair housing provide data at the ZIP code level.
• Study the impact the rule has on households' ability to use their voucher within the allowable time.
• Data from the evaluation of the Small Area FMR demonstration.
• List of ZIP codes by jurisdiction and the associated FMR rather than a list at the level of metropolitan area.
• All data used in the formula to designate the areas required to implement Small Area FMRs
• Data on whether increases to FMR for higher rent neighborhoods effectuates an increase in leasing activity in these neighborhoods.
• External evaluation of the Small Area FMR implementation parallel to implementation.
• Data not only for designated Small Area FMR areas and PHAs that opt in, but also for other areas and PHAs in order to allow comparison:
○ Number of voucher holders by ZIP code including relevant data on race, ethnicity, disability status and other factors relevant to fair housing concerns.;
○ Voucher success rates by PHA (if available and reliable); PHAs should report the average time it takes to lease-up for new and continuing voucher participants (who continue in their current jurisdiction or attempt to port their voucher);
○ Voucher turnover rates; to assess the impact of Small Area FMRs on program participants, it is essential that data is collected on the number of participants leaving and entering the program each year;
○ Voucher program exit and new admission rates by PHA;
○ Number of voucher holders with rent burdens at various levels (30 percent of income or less, 31-40 percent, 41-50 percent, and so forth) by PHA or by ZIP code;
○ Number of units on lists provided to families issued vouchers, broken down by ZIP code and PHA.
• Technical Assistance opportunities for impacted landlords and beneficiaries to understand the policy revisions and rationales.
• Information on what strategies PHAs used in conjunction with the Small Area FMRs.
• HUD should determine and publicize what payment standards PHAs use, and make this information available to help HCV households with their housing search.
○ Publicly Available ZIP-Code-Level Counts of Voucher Holders and Their Race: Currently, HUD makes the number of voucher holders in a particular area available in two ways: (1) On HUD's Open Data Web site and (2) as part of the underlying data used in the AFH Data and Mapping Tool. Both give voucher counts on the Census tract level, while the latter source includes a count of the number of non-white voucher holders in each tract. Although HUD releases a crosswalk file that matches Census tracts and ZIP Code Tabulation Areas (ZCTAs), the process of converting HUD's tract-level data to ZCTAs is complex and riddled with potential for errors. Since Small Area FMRs use ZCTAs, not Census tracts, as the primary unit of analysis, HUD should release voucher counts at the ZCTA level in order to evaluate the impact of Small Area FMRs. The data made available by race will also allow evaluation of how the Small Area FMR rule impacts jurisdictions' AFFH obligations.
• Whether increasing available asking rents impact local land use decisions.
• Data on total tenant payments by age group over the course of voucher lease-up and through Small Area FMR transitions, payment standard changes by housing agencies within Small Area FMR areas, and the use and value of PBVs.
• Availability of health services in new/old neighborhoods, the rate at which households retain their vouchers in new/old neighborhoods, and the financial costs of moving beyond rent payments (transportation, deposits, etc.).
• The ability to assess the efficacy of Small Area FMRs.
• The ability to do additional research into the Housing Choice Voucher program.
• The ability to better administer the Housing Choice Voucher program.
Commenters provided a variety of other comments regarding the proposed rule. Two of these topic areas include Moving To Work (MTW) PHAs, and comments on the methods for calculating FMRs.
Overall FMR concerns: Many commenters discussed concerns
• Specific suggestions included:
○ Fine tuning current formula to include rent variations for different bedroom size units, and ensuring that the five-year American Community Survey is keeping pace with actual rents in each ZIP code, particularly in the targeted metro areas, and to make upward adjustments as needed.
○ Alter the current FMR methodology to account for trends in local rental markets; cease using the “Trend Factor” to calculate FMRs, which measures the forecasted changes in national gross rents, and instead use the percentage change in metropolitan area-wide rents published as part of HUD PD&R's quarterly U.S. Housing Market Conditions Regional Reports.
• Revising the formula
○ Some commenters urged HUD to adopt a methodology for calculating Small Area FMRs that would better ensure access to 40% of units in all ZCTAs.
○ Urged consideration of methodology other than ZIP codes, such as independent analyses of local housing submarkets. ZIP codes may be too large to get desired impact.
○ Calculate 40th-percentile rents with data specific to different unit sizes (rather than indexing the rents to the 2-bedroom units),
○ Rely upon local rather than national CPI data in order to trend FMRs forward
OMB reviewed this final rule under Executive Order 12866 (entitled “Regulatory Planning and Review”). This rulemaking was determined to be an “economically significant regulatory action,” as defined in section 3(f)(1) of the order. The accompanying Regulatory Impact Analysis (RIA) for this rulemaking addresses the costs and benefits that would result from implementation of this final rule and the RIA can be found at
Title II of the Unfunded Mandates Reform Act of 1995 (2 U.S.C. 1531-1538) (UMRA) establishes requirements for federal agencies to assess the effects of their regulatory actions on state, local, and tribal governments and the private sector. This final rule does not impose any federal mandate on any state, local, or tribal government or the private sector within the meaning of UMRA.
This final rule concerns the establishment of fair market rent schedules and related external administrative requirements or procedures that do not constitute a development decision that affects the physical condition of specific project areas or building sites. Accordingly, under 24 CFR 50.19(c)(6), this final rule is categorically excluded from environmental review under the National Environmental Policy Act of 1969 (42 U.S.C. 4321).
The Regulatory Flexibility Act (RFA) (5 U.S.C. 601
Executive Order 13132 (entitled “Federalism”) prohibits, to the extent practicable and permitted by law, an agency from promulgating a regulation that has federalism implications and either imposes substantial direct compliance costs on state and local governments and is not required by statute or preempts state law, unless the relevant requirements of section 6 of the Executive order are met. This final rule does not have federalism implications and does not impose substantial direct compliance costs on state and local governments or preempt state law within the meaning of the Executive order.
The Catalog of Federal Domestic Assistance number for 24 CFR part 982 is 14.871.
Grant programs-housing and community development, Rent subsidies.
Grant programs-housing and community development, Grant programs-Indians, Indians, Public housing, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs-housing and community development, Low and moderate income housing, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs-housing and community development, Public housing, Rent subsidies, Reporting and recordkeeping requirements.
Accordingly, for the reasons stated in the preamble, HUD amends 24 CFR parts 888, 982, 983, and 985 as follows:
42 U.S.C. 1437f and 3535d.
(a) The fair market rents (FMRs) for existing housing are determined by HUD and are used in the Section 8 Housing Choice Voucher program (HCV program) (part 982 of this title), Section 8 project-based assistance programs and other programs requiring their use. In the HCV program, the FMRs are used to determine payment standard schedules. In the Section 8 project-based assistance programs, the FMRs are used to determine the maximum initial rent (at the beginning of the term of a housing assistance payments contract).
(a)
(b)
(c)
(i) The number of vouchers under lease in the metropolitan FMR area;
(ii) The percentage of the standard quality rental stock, within the metropolitan FMR area is in small areas (ZIP codes) where the Small Area FMR is more than 110 percent of the metropolitan FMR area;
(iii) The percentage of voucher families living in concentrated low income areas;
(iv) The percentage of voucher families living in concentrated low income areas relative to the percentage of all renters within these areas over the entire metropolitan area; and
(v) The vacancy rate for the metropolitan area.
(2) For purposes of determining applicability of Small Area FMRs to a metropolitan area, the term “concentrated low-income areas” means:
(i) Those census tracts in the metropolitan FMR area with a poverty rate of 25 percent or more; or
(ii) Any tract in the metropolitan FMR area where at least 50 percent of the households earn less than 60 percent of the area median income and are designated by HUD as Qualified Census Tracts in accordance with section 42 of the Internal Revenue Code (26 U.S.C. 42).
(3) If a metropolitan area meets the criteria of paragraph (c)(1) of this section, Small Area FMRs will apply to the metropolitan area and all PHAs administering HCV programs in that area will be required to use Small Area FMRs. A PHA administering an HCV program in a metropolitan area not subject to the application of Small Area FMRs may opt to use Small Area FMRs by seeking approval from HUD's Office of Public and Indian Housing (PIH) through written request to PIH.
(4) HUD will designate Small Area FMR areas at the beginning of a Federal fiscal year, such designations will be permanent, and will make new area designations every 5 years thereafter as new data becomes available. HUD may suspend a Small Area FMR designation from a metropolitan area, or may temporarily exempt a PHA in a Small Area FMR metropolitan area from use of the Small Area FMRs, when HUD by notice makes a documented determination that such action is warranted. Actions that may serve as the basis of a suspension of Small Area FMRs are:
(i) A Presidentially declared disaster area that results in the loss of a substantial number of housing units;
(ii) A sudden influx of displaced households needing permanent housing; or
(iii) Other events as determined by the Secretary.
(5) Small Area FMRs only apply to tenant-based assistance under the HCV program. However, a PHA may elect to apply Small Area FMRs to project-based voucher (PBV) units at 24 CFR part 983
(d)
(1) Generally, FMR areas are metropolitan areas and nonmetropolitan counties. With several exceptions, the most current Office of Management and Budget (OMB) metropolitan area definitions of Metropolitan Statistical Areas (MSAs) are used because of their generally close correspondence with housing market area definitions. HUD may make exceptions to OMB definitions if the MSAs encompass areas that are larger than housing market areas. The counties deleted from the HUD-defined FMR areas in those cases are established as separate metropolitan county FMR areas. FMRs are established for all areas in the United States, the District of Columbia, and the Insular Areas of the United States.
(2) Small Area FMR areas are the U.S. Postal Service ZIP code areas within a designated metropolitan area.
(e)
(i) The most recent American Community Survey conducted by the U.S. Census Bureau, which provides statistically reliable rent data.
(ii) Locally collected survey data acquired through Address-Based Mail surveys or Random Digit Dialing (RDD) telephone survey data, based on a sampling procedure that uses computers to select statistically random samples of rental housing.
(iii) Statistically valid information, as determined by HUD, presented to HUD during the public comment and review period.
(2) Base-year recent mover adjusted FMRs are updated and trended to the midpoint of the program year they are to be effective using Consumer Price Index (CPI) data for rents and for utilities.
(f)
(2) The FMR for single room occupancy housing is 75 percent of the FMR for a zero bedroom unit.
(g)
(h)
(1) Where the PHA notice of owner selection under 24 CFR 983.51(d) was made on or before the effective dates of both the Small Area FMR designation and the PHA administrative policy, the PHA and owner may mutually agree to apply the Small Area FMR. The application of the Small Area FMRs must be prospective and consistent with the PHA administrative plan. The owner and PHA may not subsequently choose to revert back to the use of the metropolitan-wide FMRs for the PBV project. If the rent to owner will increase as a result of the mutual agreement to apply the Small Area FMRs to the PBV project, the rent increase shall not be effective until the first annual anniversary of the HAP contract in accordance with 24 CFR 983.302(b).
(2) Where the PHA notice of owner selection under 24 CFR 983.51(d) was made after the effective dates of both the Small Area FMR designation and the PHA administrative policy, the Small Area FMRs shall apply to the PBV project if the PHA administrative plan provides that Small Area FMRs are used for all future PBV projects. If the PHA chooses to implement this administrative policy, the policy must apply to all future PBV projects and the PHA's entire jurisdiction. An owner and the PHA may not subsequently choose to apply the metropolitan area FMR to the project, regardless of whether the PHA subsequently changes its administrative plan to revert to the use of metropolitan-wide FMR for future PBV projects.
(3) For purposes of this section, the term “effective date of the Small Area FMR designation” means:
(i) The date that HUD designated a metropolitan area as a Small Area FMR area; or
(ii) The date that HUD approved a PHA request to voluntarily opt to use Small Area FMRs for its HCV program, as applicable.
(4) For purposes of this section, the term “effective date of the PHA administrative policy” means the date the administrative policy was formally adopted as part of the PHA administrative plan by the PHA Board of Commissioners or other authorized PHA officials in accordance with § 982.54(a).
(i)
(i) A 50th percentile FMR area that is designated for Small Area FMRs in accordance with paragraph (c) of this section will transition to the Small Area FMRs upon the effective date of the Small Area FMR designation;
(ii) A 50th percentile metropolitan FMR area not designated as a Small Area FMRs in accordance with paragraph (c) of this section, will remain a 50th percentile FMR until the expiration of the three-year period, at which time the metropolitan area will revert to the standard FMR based on the 40th percentile rent for the metropolitan area.
(2) A PHA with jurisdiction in a 50th percentile FMR area that reverts to the standard 40th percentile FMR may request HUD approval of payment standard amounts based on the 50th percentile rent in accordance with 24 CFR 982.503(f).
(3) HUD will calculate the 50th percentile rents for certain metropolitan areas for purposes of this transition and to approve success rate payment standard amounts in accordance with 24 CFR 982.503(e). As is the case for determining 40th percentile rent, the 50th percentile rent is drawn from the distribution of rents of all units that are occupied by recent movers and adjustments are made to exclude public housing units, newly built units and substandard units.
(a)
(b)
42 U.S.C. 1437f and 3535d.
(d) * * *
(14) The process for establishing and revising payment standards, including policies on administering decreases in the payment standard during the HAP contract term (see § 982.505(d)(3)).
(23) Policies concerning application of Small Area FMRs to project-based voucher units (see § 888.113(h)).
The addition and revisions read as follows:
(b) * * *
(1) * * *
(i) * * * The PHA must revise the payment standard amount no later than 3 months following the effective date of the published FMR if a change is necessary to stay within the basic range.
(iii) A PHA that is not in a designated Small Area FMR area or has not opted to voluntarily implement Small Area FMRs under 24 CFR 888.113(c)(3) may establish exception payment standards for a ZIP code area above the basic range for the metropolitan FMR based on the HUD published Small Area FMRs. The PHA may establish an exception payment standard up to 110 percent of the HUD published Small Area FMR for that ZIP code area. The PHA must notify HUD if it establishes an exception payment standard based on the Small Area FMR. The exception payment standard must apply to the entire ZIP code area.
(iv) At the request of a PHA administering the HCV program under Small Area FMRs under § 888.113(c)(3), HUD may approve an exception payment standard for a Small Area FMR area above the 110 percent of the published FMR in accordance with conditions set forth by Notice in the
(v) The PHA may establish an exception payment standard of not more than 120 percent of the published FMR if required as a reasonable accommodation in accordance with 24 CFR part 8 for a family that includes a person with a disability. Any unit approved under an exception payment standard must still meet the reasonable rent requirements found at § 982.507.
(vi) The PHA may establish an exception payment standard of more than 120 percent of the published FMR if required as a reasonable accommodation in accordance with 24 CFR part 8 for a family that includes a person with a disability after approval from HUD. Any unit approved under an exception payment standard must still meet the reasonable rent requirements found at § 982.507.
(2) Except as described in paragraphs (b)(1)(iii) through (v) of this section, the PHA must request HUD approval to establish a payment standard amount that is higher or lower than the basic range. HUD has sole discretion to grant or deny approval of a higher or lower payment standard amount. Paragraphs (c) and (e) of this section describe the requirements for approval of a higher payment standard amount (“exception payment standard amount”).
(c) * * *
(2)
(ii)
(5)
(c) * * *
(3)
(i) If the PHA chooses to reduce the payment standard for the families currently under HAP contract during
(ii) The PHA may choose to reduce the payment standard amount for families that remain under HAP contract to the current payment standard amount in effect on the PHA voucher payment standard schedule, or may reduce the payment standard amount to an amount that is higher than the normally applicable payment standard amount on the PHA voucher payment standard schedule. The PHA may further reduce the payment standard amount for the families during the term of the HAP contract, provided the subsequent reductions continue to result in a payment standard amount that meets or exceeds the normally applicable payment standard amount on the PHA voucher payment standard schedule.
(iii) The PHA must provide the family with at least 12 months' notice that the payment standard is being reduced during the term of the HAP contract before the effective date of the change.
(iv) The PHA shall administer decreases in the payment standard amount during the term of the HAP contract in accordance with the PHA policy as described in the PHA administrative plan. The PHA may establish different policies for designated areas within their jurisdiction (
(d) * * * A PHA may establish a payment standard greater than 120 percent of the FMR by submitting a request to HUD.
(a) * * *
(2) * * *
(ii) If there is a 10 percent decrease in the published FMR in effect 60 days before the contract anniversary (for the unit size rented by the family) as compared with the FMR in effect 1 year before the contract anniversary.
42 U.S.C. 1437f and 3535d.
(a) * * *
(3) The rent to owner is also redetermined in accordance with § 983.302.
(a) * * *
(2) When there is a 10 percent decrease in the published FMR.
(b) * * *
(1) Whenever there is a 10 percent decrease in the published FMR in effect 60 days before the contract anniversary (for the unit sizes specified in the HAP contract) as compared with the FMR in effect 1 year before the contract anniversary.
42 U.S.C. 1437a, 1437c, 1437f, and 3535(d).
(b) * * *
(1) This indicator shows whether the PHA has and implements a reasonable written method to determine and document for each unit leased that the rent to owner is reasonable based on current rents for comparable unassisted units: At the time of initial leasing; if there is any increase in the rent to owner; at the HAP contract anniversary if there is a 10 percent decrease in the published fair market rent (FMR) in effect 60 days before the HAP contract anniversary. The PHA's method must take into consideration the location, size, type, quality and age of the units, and the amenities, housing services, and maintenance and utilities provided by the owners in determining comparability and the reasonable rent. (24 CFR 982.4, 24 CFR 982.54(d)(15), 982.158(f)(7) and 982.507)
(3) * * *
(i) * * *
(B) Based on the PHA's quality control sample of tenant files, the PHA follows its written method to determine reasonable rent and has documented its determination that the rent to owner is reasonable in accordance with § 982.507 of this chapter for at least 98 percent of units sampled at the time of initial leasing, if there is any increase in the rent to owner, and at the HAP contract anniversary if there is a 10 percent decrease in the published FMR in effect 60 days before the HAP contract anniversary. 20 points.
(ii) The PHA's SEMAP certification includes the statements in paragraph (b)(3)(i) of this section, except that the PHA documents its determination of reasonable rent for only 80 to 97 percent of units sampled at initial leasing, if there is any increase in the rent to owner, and at the HAP contract anniversary if there is a 10 percent decrease in the published FMR in effect 60 days before the HAP contract anniversary. 15 points.
(i) * * *
(1) * * * For purposes of this paragraph, payment standards that do not exceed 110 percent of the current applicable published FMRs include exception payment standards established by the PHA in accordance with 982.503(c)(iii).
The Regulatory Impact Analysis of the final Small Area Fair Market Rent (Small Area FMR) rule identifies two types of small entities that would be affected by the rule: Small Public Housing Agencies (PHAs) and small private landlords. The Final Regulatory Flexibility Analysis (FRFA) furthers the analysis of the impact of the rule on small entities by including more data on the relevant sectors as well as a more rigorous definition of what is a “small” PHA. The analysis of the final rule satisfies Section 604 of the Regulatory Flexibility Act. The requirements of the FRFA are listed below.
(a) Each final regulatory flexibility analysis required under this section shall contain—
(1) A statement of the need for, and objectives of, the rule:
(2) A statement of the significant issues raised by the public comments in response to the initial regulatory flexibility analysis, a statement of the assessment of the agency of such issues, and a statement of any changes made in the proposed rule as a result of such comments;
(3) The response of the agency to any comments filed by the Chief Counsel for Advocacy of the Small Business Administration in response to the proposed rule, and a detailed statement of any change made to the proposed rule in the final rule as a result of the comments;
(4) A description of and an estimate of the number of small entities to which the rule will apply or an explanation of why no such estimate is available:
(5) A description of the projected reporting, recordkeeping and other compliance requirements of the rule, including an estimate of the classes of small entities which will be subject to the requirement and the type of professional skills necessary for preparation of the report or record:
(6) A description of the steps the agency has taken to minimize the significant economic impact on small entities consistent with the stated objectives of applicable statutes, including a statement of the factual, policy, and legal reasons for selecting the alternative adopted in the final rule and why each one of the other significant alternatives to the rule considered by the agency which affect the impact on small entities was rejected:
(b) The agency shall make copies of the final regulatory flexibility analysis available to members of the public and shall publish in the
HUD expects a variety of economic effects stemming from implementation of the final rule. Transfers involving vouchers would be the most sizable of those effects. PHAs will face both costs and benefits from the implementation of this rule. Social benefits and costs associated with the rule could be generated by a new settlement pattern among voucher holders. Quantified incremental impacts include an expected transfer of $151 million among participants and $2 million of implementation costs to PHAs. The Regulatory Impact Analysis accompanying the final rule includes a lengthy description of qualitative impacts as well details concerning the calculation of the quantitative impacts.
Section 2 documents the need for the final Small Area FMR rule as well as the objectives of the final rule.
This final rule requires the use of Small Area Fair Market Rents (Small Area FMRs) in the administration of the Housing Choice Voucher (HCV) program for certain metropolitan areas. HUD is implementing the use of Small Area FMRs in place of the current 50th percentile rent to address high levels of voucher concentration. HUD believes that Small Area FMRs gives HCV tenants a more effective means to move into areas of higher opportunity and lower poverty areas by providing them with subsidy adequate to make such areas accessible and to thereby reduce the number of voucher families that reside in areas of high poverty concentration.
HUD is using several criteria to determine which metropolitan areas would best be served by application of Small Area FMRs in the administration of the HCV program. These criteria include a threshold number of vouchers within a metropolitan area, the concentration of current HCV tenants in low-income areas, and the percentage of renter occupied units within the metropolitan area with Small Area FMRs above the payment standard basic range. Public housing agencies (PHAs) operating in designated metropolitan areas would be required to use Small Area FMRs. PHAs not operating in the designated areas would have the option to use Small Area FMRs in administering their HCV programs. Other programs that use FMRs would continue to use area-wide FMRs.
HUD's current rule for addressing high concentrations of voucher tenants in metropolitan areas, the 50th percentile Fair Market Rent rule, has not succeeded in providing voucher tenants access to high opportunity areas within a Fair Market Rent area. Therefore, the Small Area FMR rule is needed to replace the current regulatory provision with a new framework intended to provide voucher families with increased opportunities to find suitable units in higher opportunity areas.
This final rule, through establishment of Small Area FMRs as a means of setting rents in certain metropolitan areas, is intended to facilitate the Housing Choice Voucher (HCV) program in achieving two program objectives: (1) Increasing the ability of low-income families to find and lease decent and affordable housing; and (2) providing low-income families with access to a broad range of housing opportunities throughout a metropolitan area. HUD's goal in pursuing this rulemaking is to provide HCV tenants with a greater ability to move into areas where jobs, transportation, and educational opportunities exist.
No public comments were filed that discussed or provided feedback on the Initial Regulatory Flexibility Analysis. Consequently, there is nothing for HUD to assess regarding these types of comments and no changes were made to the proposed rule based on IRFA comments.
No public comments were filed from the Chief Counsel for Advocacy of the Small Business Administration. The Small Business Administration provided comments during the interagency clearance process preceding publication of the proposed rule that were incorporated in the published document; however, no further changes to the proposed rule were made.
The Small Business Administration defines a lessor of residential real estate to be a small business if it earns annual revenues (sales receipts) of less than $27.5 million. In the 2012 Economic Census, the Census counted approximately 50,000 of which approximately 43,000 operated for the entire year of 2012. Our comparisons are made
Of the 42,911 firms operating all year, 42,618 can be considered small firms. Total annual revenue of the industry was $84 billion,
HUD is able to provide information on the number of owners who participate in the housing choice voucher program. Note that counting real estate owners is not equivalent to lessors that operate the property. One would expect there to be many more owners than lessors. Nonetheless, the data provides insight as to the distribution of vouchers. It is evident that the overwhelming proportion of owners rent to very few voucher tenants. Approximately two-thirds of owners who rent to voucher tenants rent to only one voucher tenant household. Many of these are likely owners of single-family homes for whom the rental income is not the primary source of income. Approximately 90 percent rent to no more than 4 voucher tenant households, which could be housed in a large two-story building. Very few owners rent to enough voucher tenants to occupy multiple buildings.
The data on the distribution of owners by number of vouchers implies that industry structure is not significantly different for vouchers than for other residential rental properties. The tables do not correspond perfectly because one describes property managers and the other property owners. In addition, the table for owners shows information for voucher tenants only and does not include any unassisted tenants.
HUD estimates that 18 percent of all vouchers are likely to be affected by the rule. If the number of lessor firms is proportional to the number of vouchers, then approximately 7,700 firms operating all year round (or 9,000 firms operating at any time) would manage units in Small Area FMR areas. They do not necessarily provide housing for voucher tenants but would be affected by any market externalities engendered by the rule. The median share of voucher holders in a census tract is 3.1 percent. Again, assuming proportionality we expect 400-500 NAICS industry 531110 firms to manage units occupied by voucher tenants in the Small Area FMR areas created by the proposed rule. The number of voucher units managed by any one firm will vary.
There are two types of possible effects of the rule on property owners and managers. The first is
The second type of effect is
The final rule does not impose any additional reporting, recordkeeping and other compliance requirements. Compliance and unit standards remain the same. An additional effect of the rule is that eight current 50th percentile areas will revert to 40th percentile FMRs, as the Small Area FMR rule uses different selection criteria than the 50th percentile rule. These areas currently cover 82,000 vouchers. On average, the FY16 40th percentile FMR is $77 lower than the 50th percentile FMR, meaning a
PHAs operating in metropolitan areas that meet the established Small Area FMR criteria of the final rule will be required to use Small Area FMRs in their HCV programs. As of issuance of this final rule, there are 24 areas listed that meet these criteria. These areas contain approximately 368,000 (18 percent) of the HCV households nationwide.
A small PHA is defined by HUD to be one of less than 250 units.
PHAs administering Small Area FMRs will likely face higher administrative costs. Initial costs would include training employees and setting up new systems. Periodic costs include costs related to payment standard and rent determinations as well any increase in moves and contract rent changes than those operating under one metropolitan FMR. PHAs change their payment standards as the FMR changes. Once the payment standard is established, and the PHA board approves, the PHA creates materials to inform their customers (and landlords) of the new payment standards. Making the transition from one to many payment standards is likely to impose some burden at initial implementation of the Small Area FMR rule.
There are at least two ways that a PHA would respond to the increased complexity of multiple payment standards. First, it could pursue a more labor-intensive solution and ask staff to determine the payment standard manually. This would not be particularly difficult for a small PHA with few payment standards. Small PHAs typically have smaller service areas with fewer ZIP codes and therefore fewer Small Area FMR-based payments standards to determine and administer than do larger PHAs. Another solution is to make an upfront investment to automate the process of subsidy determination. A unit's address is already entered into a PHA's database. All that is needed is a tool that calculates the rental subsidy as a function of the address. HUD has the intention of developing such an application for PHAs and voucher holder tenants. For it to work, PHAs will have to provide data on their payment standard decisions to HUD. Thus, compliance costs of PHAs are expected to rise slightly but not significantly. Because the tool will be developed, tested, and provided by HUD, it is not expected that the cost of implementation will be disproportionate.
A 2015 study
The Small Area FMR rule will be beneficial to PHAs in some important respects. First, the rule intends to eliminate the possibility that an area will cycle in and out of the 50th percentile FMR as it can currently occur under the 2000 rule. This change is expected to reduce the year-to-year administrative uncertainty and the costs of adjusting the program to changing FMR calculations over time. Second, the final rule is also expected to facilitate PHA and regional compliance with consolidated planning and Fair Housing requirements and allow counseling and similar efforts to be more effective.
Under the Final Regulatory Flexibility Analysis, HUD must discuss alternatives that minimize the economic impact on small entities. In order to lessen the burden on PHAs, and specifically small PHAs, HUD has taken, or is committed to taking, several measures in implementing Small Area FMRs designed to facilitate transition to this approach and minimize costs and burdens. Specifically, HUD is pursuing the following strategies to mitigate adverse impacts:
•
•
•
•
In addition to the above, the presentation of the information in HUD's proposed revision to its PHA administrative fee formula would also soften any adverse impact by providing additional resources to small PHAs generally.
The majority of lessors of residential real estate and a substantial fraction of PHAs are characterized as small. If there were disproportionate effects on small entities, then a more detailed regulatory flexibility analysis would be merited. However, after an in-depth discussion of the industry structure and impact of the rule, HUD cannot conclude that there is a significant and disproportionate impact on small entities. It is true that many lessors may receive income from voucher tenants but it is not likely that they will be adversely affected once market forces are accounted for. Small PHAs could face an additional administrative burden but HUD has offered solutions to significantly reduce any burden.
Internal Revenue Service (IRS), Treasury.
Correcting amendment.
This document contains corrections to final regulations (TD 9787) that were published in the
This correction is effective November 16, 2016 and is applicable on and after October 5, 2016.
Deane M. Burke or Caroline E. Hay at (202) 317-5279 (not a toll-free number).
The final regulations (TD 9787) that are the subject of this correction are under sections 707 and 752 of the Internal Revenue Code.
As published, the final regulations (TD 9787) contain errors that may prove to be misleading and are in need of clarification.
Income taxes, Reporting and recordkeeping requirements.
26 U.S.C. 7805 * * *
Section 1.707-5 also issued under 26 U.S.C. 707(a)(2)(B).
Bureau of Safety and Environmental Enforcement, Interior.
Final rule.
This rule amends Bureau of Safety and Environmental Enforcement (BSEE) regulations requiring lessees and owners of operating rights to submit summaries of actual decommissioning expenditures incurred for certain decommissioning activities related to oil and gas and sulfur operations on the Outer Continental Shelf (OCS). The amendment requires lessees, owners of operating rights, and right-of-way (ROW) holders to submit summaries of actual expenditures incurred for pipeline decommissioning activities.
This final rule becomes effective on December 16, 2016.
Betty Cox, Regulatory Analyst, Regulations and Standards Branch at
BSEE promotes safety, protects the environment, and conserves natural resources through vigorous regulatory oversight and enforcement regarding certain activities on the OCS. BSEE derives its authority primarily from the Outer Continental Shelf Lands Act (OCSLA), 43 U.S.C. 1331-1356a. Congress enacted OCSLA in 1953, codifying Federal control over the OCS and authorizing the Secretary of the Interior (Secretary) to, among other things, regulate oil and natural gas exploration, development, and production operations and to grant rights-of-way on the OCS. The Secretary has authorized BSEE to perform certain of these functions, including overseeing decommissioning. (
Among its responsibilities, BSEE regulates certain types of oil and gas pipelines used on the OCS. (
In 2009, BSEE's predecessor agency, the Minerals Management Service (MMS), proposed new reporting requirements related to lease assignment for lease term pipelines. (
In a final rule published on December 4, 2015, BSEE amended its regulations to require lessees and owners of operating rights to submit summaries of actual decommissioning expenditures for certain required decommissioning activities within 120 days after completion of each such activity. (
On April 27, 2016, BSEE issued a Notice to Lessees and Operators (NTL), No. 2016-N03,
BSEE did not include reporting of expenditures for pipeline decommissioning in the December 2015 final rule because the 2009 proposed rule did not expressly refer to pipeline decommissioning expenditures. BSEE has determined, however, that accurate information about expenditures incurred for pipeline decommissioning activities is needed to better estimate future decommissioning costs for those activities.
As BSEE explained in the December 2015 final rule, with regard to expenditures for other types of decommissioning activities, summaries of actual decommissioning expenditures will help BSEE better estimate future decommissioning costs. (
Accordingly, on August 12, 2016, BSEE published a proposed rule to extend the existing decommissioning cost reporting regulations to require lessees, owners of operating rights, and pipeline ROW holders to submit information regarding actual expenditures incurred for activities related to decommissioning of pipelines. (
For the reasons stated in the proposed rule and based on BSEE's evaluation of the public comments received, this rule finalizes the proposal to require lessees, owners of operating rights, and pipeline ROW holders to submit information reflecting actual expenditures incurred for the decommissioning of pipelines.
BSEE has made no changes to the language of the proposed rule and is finalizing the regulatory text as proposed.
In response to the proposed rule, BSEE received one comment, which was submitted by a trade association representing producing companies and service providers to the offshore oil and natural gas industry. The full text of the comment can be viewed at:
Regarding the commenter's assertion that 120 days may not be enough time to submit a certified summary based on actual invoice data, BSEE expects to apply the same guidance under this new rule as that contained in NTL No. 2016-N03,
BSEE appreciates that there could be situations where it may take longer than the 120-day reporting period allowed by regulation for lessees to receive and process all decommissioning related invoices. In such cases, BSEE will consider granting an extension when timely requested and sufficiently justified. BSEE would rather receive a single complete submission with a reporting period extension than a preliminary summary followed by some number of revisions/supplements. However, failure to submit decommissioning cost summaries in the timeframe required by the regulation, or as extended by BSEE, may result in BSEE's issuance of an Incident of Noncompliance.
BSEE expects to address any special situations that may warrant an extension of the deadline for submitting a summary of pipeline decommissioning expenditures in the same manner as requests to extend the deadline for summaries of other decommissioning costs.
Executive Order (E.O.) 12866 provides that the Office of Management and Budget (OMB), Office of Information and Regulatory Affairs (OIRA), will review all significant regulatory actions. BSEE has determined that this final rule is not a significant regulatory action as defined by section 3(f) of E.O. 12866 because:
• It is not expected to have an annual effect on the economy of $100 million or more;
• It will not adversely affect in a material way the economy, productivity, competition, jobs, the environment, public health or safety, or State, Tribal, or local governments or communities;
• It will not create a serious inconsistency or otherwise interfere with an action taken or planned by another agency;
• It will not materially alter the budgetary impact of entitlements, grants, user fees, or loan programs, or the rights or obligations of their recipients; and
• It will not raise novel legal or policy issues arising out of legal mandates, the President's priorities, or the principles set forth in E.O. 12866.
Accordingly, BSEE has not prepared an economic analysis beyond the analysis required under the Paperwork Reduction Act, and OIRA has not reviewed this rule under E.O. 12866. E.O. 13563 reaffirms the principles of E.O. 12866 while calling for improvements in the Nation's regulatory system to promote predictability, reduce uncertainty, and use the best, most innovative, and least burdensome tools for achieving regulatory ends. E.O. 13563 directs agencies to consider regulatory approaches that reduce burdens and maintain flexibility and freedom of choice for the public where these approaches are relevant, feasible, and consistent with regulatory objectives. It also emphasizes that regulations must be based on the best available science and that the rulemaking process must allow for public participation and an open exchange of ideas. BSEE developed this rule in a manner consistent with these requirements.
BSEE certifies that this final rule will not have a significant economic effect on a substantial number of small entities under the RFA (5 U.S.C. 601
This final rule will affect some additional companies (
However, because the final rule requires only summary reports of actual expenditures related to pipeline decommissioning activities, it will not impose significant new economic impacts on any affected small entities. The requirement to submit pipeline decommissioning cost summaries will not result in significant additional costs or burdens for any affected entity. As indicated in the Paperwork Reduction Act section of this document, the annual burden of the rule is estimated to be only 519 hours in total for all affected entities to prepare and submit their pipeline decommissioning cost summaries. Accordingly, since the changes reflected in this final rule will not have a significant economic effect on a substantial number of small entities, the RFA does not require BSEE to prepare a regulatory flexibility analysis for this rule.
This rule is not a major rule under the SBREFA (5 U.S.C. 804(2)). This final rule will not:
• Have an annual effect on the economy of $100 million or more;
• Cause a major increase in costs or prices for consumers, individual industries, Federal, State, or local government agencies, or geographic regions; or
• Have significant adverse effects on competition, employment, investment, productivity, innovation, or the ability of U.S.-based enterprises to compete with foreign-based enterprises.
Your comments are important. The Small Business and Agriculture Regulatory Enforcement Ombudsman and 10 Regional Fairness Boards were established to receive comments from small businesses about Federal agency enforcement actions. The Ombudsman will annually evaluate the enforcement activities and rate each agency's responsiveness to small business. If you wish to comment on the actions of BSEE, call 1-888-734-3247. You may comment to the Small Business Administration (SBA) without fear of retaliation. Allegations of discrimination/retaliation filed with the SBA will be investigated for appropriate action.
This final rule will not impose an unfunded mandate on State, Tribal, or local governments or the private sector of more than $100 million per year. This rule also will not have a significant or unique effect on State, Tribal, or local governments or the private sector. Thus, a statement containing the information required by the Unfunded Mandates Reform Act (2 U.S.C. 1531
Under the criteria in E.O. 12630, this final rule will not effect a taking or otherwise have takings implications. This rule is not a governmental action capable of interference with constitutionally protected property rights. Therefore, a Takings Implication Assessment is not required.
Under the criteria in Executive Order 13132, this final rule does not have federalism implications. This rule will not have a substantial direct effect on the States or the relationship between the Federal and State governments. To the extent that State and local governments have a role in OCS activities, this final rule will not affect that role. Accordingly, a federalism summary impact statement is not required.
This final rule complies with the requirements of Executive Order 12988 (E.O. 12988),
• Meets the criteria of section 3(a) of E.O. 12988 requiring that all regulations be reviewed to eliminate drafting errors and ambiguity and be written to minimize litigation; and
• Meets the criteria of section 3(b)(2) of E.O. 12988 requiring that all regulations be written in clear language and contain clear legal standards.
We have evaluated this final rule under the Department's tribal consultation policy, under Departmental Manual Part 512 Chapters 4 and 5, and under the criteria in E.O. 13175 and have determined that it will have no substantial direct effects on federally recognized Indian tribes. As a result, consultation under the Department's tribal consultation policy is not required.
This rule contains new information collection (IC) requirements and submission to the OMB under the PRA of 1995 (44 U.S.C. 3501
The title of the collection of information for this rule is
Once the requirements of this rulemaking have been codified, BSEE will consolidate these additional burden
The following table is a breakdown of the burden estimate:
We received one comment in response to the proposed rule pertaining to the information collection. Please see the Summary of and Responses to Public Comments section in this preamble. Based on the comment received, we are increasing the burden to reflect requests for extension to the 120-day reporting period (+ 19 hours).
An agency may not conduct or sponsor, and you are not required to respond to, a collection of information unless it displays a currently valid OMB control number. The public may comment at any time on the accuracy of the IC burden in this rule and may submit any comments to the Department of the Interior, Bureau of Safety and Environmental Enforcement, Attention: Regulations and Standards Branch, VA-ORP, 45600 Woodland Road, Sterling, VA 20166.
This rule meets the criteria set forth in 516 Departmental Manual (DM) 15.4C(1) for a categorical exclusion because it involves modification of existing regulations, the impacts of which would be limited to administrative or economic effects with minimal environmental impacts.
We have also analyzed this rule to determine if it involves any of the extraordinary circumstances set forth in 43 CFR 46.215 that would require an environmental assessment or an environmental impact statement for actions otherwise eligible for a categorical exclusion. We have concluded that this rule does not involve any of the listed extraordinary circumstances.
In developing this rule, we did not conduct or use a study, experiment, or survey requiring peer review under the Data Quality Act (44 U.S.C. 3516
This rule is not a significant energy action under Executive Order 13211 (E.O. 13211) because:
• It is not a significant regulatory action under E.O. 12866;
• It is not likely to have a significant adverse effect on the supply, distribution or use of energy; and
• It has not been designated as a significant energy action by the Administrator of OIRA.
Administrative practice and procedure, Continental shelf, Environmental impact statements, Environmental protection, Government contracts, Investigations, Oil and gas exploration, Penalties, Reporting and recordkeeping requirements, Sulfur.
For the reasons stated in the preamble, BSEE amends 30 CFR part 250 as follows:
30 U.S.C. 1751, 31 U.S.C. 9701, 33 U.S.C. 1321(j)(1)(C), 43 U.S.C. 1334.
Office of Surface Mining Reclamation and Enforcement, Department of the Interior.
Notice of availability; final environmental impact statement.
We, the Office of Surface Mining Reclamation and Enforcement (OSMRE), announce the availability of the Final Environmental Impact Statement (FEIS) for the Stream Protection Rule developed pursuant to the National Environmental Policy Act (NEPA).
The final EIS is available on November 16, 2016.
Copies of the FEIS are available for public inspection at the following OSMRE locations:
• Administrative Record, Room 101 SIB, 1951 Constitution Avenue NW., Washington, DC 20240, (Phone: 202-208-2823).
• Appalachian Regional Office, Three Parkway Center, Pittsburgh, Pennsylvania 15220 (Phone: (412) 937-2815).
• Mid-Continent Regional Office, William L. Beatty Federal Building, 501 Belle Street, Room 216, Alton, Illinois 62002 (Phone: (618) 463-6460).
• Western Regional Office, 1999 Broadway, Suite 3320, Denver, Colorado 80201 (Phone: (303) 293-5000).
• Charleston Field Office, 1027 Virginia Street East, Charleston, West Virginia 25301 (Phone: (304) 347-7158).
• Knoxville Field Office, 710 Locust Street, 2nd floor, Knoxville, Tennessee 37902 (Phone: (865) 545-4103).
• Lexington Field Office, 2675 Regency Road, Lexington, Kentucky 40503 (Phone: (859) 260-3902).
• Beckley Area Office, 313 Harper Park Drive, Beckley, West Virginia 25801 (Phone: (304) 255-5265).
• Harrisburg Area Office, 215 Limekiln Road, New Cumberland, Pennsylvania 17070 (Phone: (717) 730-6985).
• Albuquerque Area Office, 100 Sun Avenue NE., Pan American Building, Suite 330, Albuquerque, New Mexico 87109 (Phone: (505) 761-8989).
• Casper Area Office, Dick Cheney Federal Building, 150 East B Street, Casper, Wyoming 82601 (Phone: (307) 261-6550).
• Birmingham Field Office, 135 Gemini Circle, Suite 215, Homewood, Alabama 35209 (Phone: (205) 290-7282).
• Tulsa Field Office, 1645 South 101st East Avenue, Suite 145, Tulsa, Oklahoma 74128 (Phone: (918) 581-6430).
Electronic copies of the FEIS are available at:
•
• OSMRE Web site:
In addition, a limited number of CD copies of the FEIS are available upon request. You may obtain a CD by contacting the person identified in
Robin Ferguson, Office of Surface Mining Reclamation and Enforcement, U.S. Department of the Interior, 1951 Constitution Avenue NW., Washington, DC 20240. Telephone: 202-208-2802. Email:
Significant advances in scientific knowledge and mining and reclamation techniques have occurred in the more than 30 years that have elapsed since the enactment of the Surface Mining Control and Reclamation Act of 1977, 30 U.S.C. 1201
The draft environmental impact statement (DEIS) for the proposed rule was made available for public review and comment on July 17, 2015. (
The FEIS for the Stream Protection Rule analyzes the environmental, socioeconomic, and other effects of the preferred alternative—Alternative 8, as revised—and a reasonable range of other alternatives, including a No Action Alternative. The FEIS, including Alternative 8, has been revised, as appropriate, in response to comments and other information received on the DEIS, proposed rule, and draft Regulatory Impact Analysis. It also includes the input of cooperating agencies.
40 CFR 1506.6, 40 CFR 1506.1
Environmental Protection Agency (EPA).
Final rule; notice of data availability (NODA).
The Environmental Protection Agency (EPA) is providing notice of emission allowance allocations to certain units under the new unit set-aside (NUSA) provisions of the Cross-State Air Pollution Rule (CSAPR) federal implementation plans (FIPs). EPA has completed final calculations for the second round of NUSA allowance allocations for the 2016 compliance year of the CSAPR NO
November 16, 2016.
Questions concerning this action should be addressed to Robert Miller at (202) 343-9077 or
Under the CSAPR FIPs, a portion of each state budget for each of the four CSAPR trading programs
EPA received no objections to the preliminary lists of new units eligible for second-round 2016 NUSA allocations of CSAPR NO
As described in the September 14 NODA, any allowances remaining in the CSAPR NO
Under 40 CFR 97.512(b)(10), any allowances remaining in the CSAPR NO
The final unit-by-unit data and allowance allocation calculations are set forth in Excel spreadsheets titled “CSAPR_NUSA_2016_NOx_OS_2nd_Round_Final_Data_New_Units”, and “CSAPR_NUSA_2016_NOx_OS_2nd_Round_Final_Data_Existing_Units”, available on EPA's Web site at
Pursuant to CSAPR's allowance recordation timing requirements, the allocated NUSA allowances will be recorded in sources' AMS accounts by November 15, 2016. EPA notes that an allocation or lack of allocation of allowances to a given unit does not constitute a determination that CSAPR does or does not apply to the unit. EPA also notes that NUSA allocations of CSAPR NO
40 CFR 97.511(b).
Centers for Medicare & Medicaid Services (CMS), HHS.
Final rule; correction.
This document corrects typographical errors that appeared in the final rule published in the
This correcting document is effective November 15, 2016.
Ronisha Blackstone, (410) 786-6882.
In FR Doc. 2016-21404 which appeared in the September 16, 2016
On page 64030, we inadvertently omitted a paragraph number (that is, paragraph (xii)) in numbering the paragraphs in § 482.15(h)(1).
On page 64032, we inadvertently omitted a paragraph number (that is, paragraph (xii)) in numbering the paragraphs in § 483.73(g)(1).
On page 64034, we made a typographical error in numbering the paragraphs in § 484.22(d)(1).
On page 64037, we inadvertently omitted a paragraph number (that is, paragraph (xii)) in numbering the paragraphs in § 485.625(g)(1).
We ordinarily publish a notice of proposed rulemaking in the
Section 553(d) of the APA ordinarily requires a 30-day delay in effective date of final rules after the date of their publication in the
We believe that this correcting document does not constitute a rule that would be subject to the APA notice and comment or delayed effective date requirements. This correcting document corrects typographical errors in the regulations text of the final rule but does not make substantive changes to the policies that were adopted in the final rule. As a result, this correcting document is intended to ensure that the regulations text in the final rule accurately reflect the policies adopted in that final rule.
In addition, even if this were a rule to which the notice and comment procedures and delayed effective date requirements applied, we find that there is good cause to waive such requirements. Undertaking further notice and comment procedures to incorporate the corrections in this document into the final rule or delaying the effective date would be contrary to the public interest because it is in the public's interest for providers and suppliers to receive the appropriate revisions in as timely a manner as possible, and to ensure that the Emergency Preparedness Requirements for Medicare and Medicaid Participating Providers and Suppliers final rule accurately reflects our policies. Furthermore, such procedures would be unnecessary, as we are not altering our policies, but rather, we are simply implementing correctly the policies that we previously proposed, received comment on, and subsequently finalized. This correcting document is intended solely to ensure that the Emergency Preparedness Requirements for Medicare and Medicaid Participating Providers and Suppliers final rule accurately reflects these revisions. Therefore, we believe we have good cause to waive the notice and comment and effective date requirements.
In FR Doc. 2016-21404 of September 16, 2016 (81 FR 63860), make the following corrections:
Federal Communications Commission.
Final rule.
In this document, the Commission modifies its rules under the Telephone Consumer Protection Act (TCPA) to implement a provision of the Bipartisan Budget Act of 2015 that excepts from the TCPA's prior-express-consent requirement autodialed and prerecorded calls “made solely to collect a debt owed to or guaranteed by the United States.” While certain debt servicing calls are permitted under the
This Order was issued August 11, 2016.
Kristi Thornton, Consumer Policy Division, Consumer and Governmental Affairs Bureau, at (202) 418-2467 or email:
This is a summary of the Commission's
1. The Commission adopts rules to implement the Budget Act's amendments to the TCPA, including—based on substantial record support, and in furtherance of the TCPA's consumer-protection goals—restrictions on the number and duration of calls that may be made pursuant to the amendments. Among other things, the Commission determines who may make covered calls, limits the number of federal debt collection calls that may be made, and determines who may be called. The Commission also creates rules to, among other things:
• Permit calls made by debt collectors when the loan is in delinquency, and by debt servicers following a specific, time-sensitive event affecting the amount or timing of payment due, and in the 30 days before such an event.
• Determine that consumers have a right to stop the autodialed, artificial-voice, and prerecorded-voice servicing and collection calls regarding a federal debt to wireless numbers at any point the consumer wishes.
• Specify that covered calls may be made by the owner of the debt or its contractor, to: (1) The wireless telephone number the debtor provided at the time the debt was incurred; (2) a phone number subsequently provided by the debtor to the owner of the debt or its contractor; and (3) a wireless telephone number the owner of the debt or its contractor has obtained from an independent source, provided that the number actually is the debtor's telephone number.
2. Once information collection requirements of the revised § 64.1200(j)(3), (j)(4) have been approved by the Office of Management and Budget (OMB), the Commission will publish a document in the
3. “
4. The Commission rejects a subjective standard of what a caller may intend when determining whether a call is a covered call and instead looks to objective characteristics of the call. The Commission notes that an objective standard is consistent with its approach to other aspects of the TCPA, such as the meaning of “called party” for purposes of reassigned wireless numbers. Furthermore, a subjective standard would be difficult to administer, while an objective standard enables the Commission to look at actual, measurable characteristics of a call.
5. In the
6. The Commission interprets “solely to collect a debt,” and, therefore, calls made pursuant to the exception created in the Budget Act, to be limited to debts that are delinquent at the time the call is made or to debts that are at imminent risk of delinquency as a result of the terms or operation of the loan program itself. As a practical matter, this means that, at the time the call is made, the debt is delinquent or there is an imminent, non-speculative risk of delinquency due to a specific, time-sensitive event that affects the amount or timing of payments due, such as a deadline to recertify eligibility for an alternative repayment plan or the end of a deferment period. Many federal loan programs offer various alternate and income-based repayment options for which a debtor might qualify at various times during the life of the debt, and the amount or timing of payments due can vary significantly following expiration of a deferral period or an alternate payment plan. For example, some income-based repayment plans for student loans allow a debtor to make a monthly payment of zero dollars without being considered delinquent or in default, but higher monthly payments are required automatically if the debtor does not periodically recertify that he continues to qualify for the program. As such, calls regarding changes in the amount or timing of payments are directly related to the collection of the underlying debt in that they can ensure payments that would likely otherwise would not be made.
7. Some commenters argue that the Commission may not limit covered calls to those that are “delinquent” or in “default” because the Budget Act did not include such limiting language. For example, ACA states: “Congress made absolutely no mention of the [exception] being limited to calls made post delinquency or post-default. As a result it would be inappropriate for the Commission to read such a limitation into the amendment.” The Commission disagrees with regard to its discretion to interpret the statutory language, but notes that it is not limiting covered calls
8. Other commenters argue that covered calls should begin before delinquency because calls that occur after delinquency or default are “too late to prevent damage to the consumer's credit profile and fail[] to allow the borrower to receive timely information to choose the repayment plan best suited for the borrower's unique circumstances.” The Commission agrees. Certain calls to service a debt owed to or guaranteed by the government may be so closely tied to an imminent and non-speculative risk of delinquency as to also be “solely to collect a debt.” These calls pertain to specific, time-sensitive events that affect the amount or timing of payments due. Once these time-sensitive events are sufficiently imminent, calls about these events are no longer just about a debt, but are solely about the collection of a debt. The time-sensitive nature of these calls necessitates that they are “solely to collect a debt” for only a limited time—following the event and in the 30 days before such an event. Any earlier and the calls are too speculative and attenuated for the purpose of the call to be “solely to collect a debt.”
9. The record indicates that these debt servicing calls help a debtor avoid delinquency or default, which can preserve the debtor's payment history and credit rating, and help maintain eligibility for future loans. The potential value of these servicing calls to debtors by helping them avoid delinquency or default, and the probability that servicing calls will create conditions that allow debts to be more readily collected by the United States, lead the Commission to determine that certain servicing calls should be included in the interpretation of “solely to collect a debt.”
10. A caller, therefore, need not wait until a debtor is delinquent to begin making certain debt servicing calls. Rather a caller may make debt servicing calls following a specific, time-sensitive event that affects the amount or timing of payments due, such as a recertification deadline or the end of a deferment period, and in the 30 days before such an event. For purposes of the limits on the number of covered calls, no debt servicing calls will be permitted except those regarding an approaching deadline or a change in status (deferment, forbearance, rehabilitation), calls regarding enrollment or reenrollment in income-driven or income-based repayment plans, and calls regarding similar time-sensitive events or deadlines affecting the amount or timing of payments due. While commenters list other pre-delinquency calls they would like the Commission to include in the list of debt servicing calls for purposes of the Budget Act amendments, the Commission declines to do so. This list of calls the Commission is permitting as covered debt servicing calls includes the most-requested debt servicing calls and includes calls both to enroll debtors in consumer-friendly programs and to keep them enrolled in those programs. It also includes calls aimed at alerting debtors when significant events will occur that will change their payment patterns. The list does not include calls regarding routine events, such as reminders about scheduled upcoming payments. The Commission would consider a routine event one that occurs by operation of the contract alone, as contrasted with the events described above, which require affirmative steps by the debtor to take advantage of the provisions of the debt contract. These included calls, which often increase the probability that debts will be more readily collected and that a debtor will avoid delinquency, achieve the desired result of enabling the caller to collect a debt owed to or guaranteed by the United States and simultaneously can benefit the debtor. The Commission's interpretation of covered calls permit no debt servicing calls unless the call follows one of these specific, time-sensitive events, and in the 30 days before such an event.
11. “
12. The Commission clarifies that the debt must be
13.
14. Other commenters, however, urge the Commission to permit covered calls to persons other than the debtor. Navient, in particular, comments on the need to call the parents, relatives, and references of a borrower in order to locate the borrower. Navient writes: “[C]alling numbers obtained through skip tracing is sometimes the only way to reach a defaulted borrower.” It also notes that the Department of Education requires “lenders to contact every `endorser, relative, reference, individual, and entity' identified in a delinquent borrower's loan file as part of their due diligence efforts.” Navient fails to note, however, that there is no requirement to make these contacts via robocall. Navient also makes clear in its comments that its purpose in calling relatives and references is to locate the debtor, not to collect the debt. Because the language of the Budget Act authorizes the Commission to limit calls “solely to collect a debt,” the rules permit covered calls only to persons who are responsible for repaying the debt.
15.
16. The Commission notes that the rules it is adopting, which permit calls only if they are to these three categories of numbers, are broader than the proposal in the
17. This limitation the Commission is placing on the number of covered calls, which limits covered calls only to these three categories of numbers, is a determination that robocalls to wrong numbers are not covered by the exception created in the Budget Act amendments. Calls to reassigned wireless numbers may not be made pursuant to the exception either. Wrong numbers, as the Commission used the term in the
18. Numerous parties in the record urge the Commission to apply the same wrong number and reassigned number standards set forth in the
19.
20.
21.
22.
23.
24.
25.
26. As these comments demonstrate, there is no consensus in the record. The Department of Education states that it “does not believe that allowing loan servicers and [private collection agencies] to make three [federal debt collection calls] per month would measurably increase the likelihood that they would reach a borrower,” but that “a higher limit will reasonably allow” them to do so. Consumer groups generally argue that three calls is the appropriate number for calls pursuant to the Budget Act amendments. As commenter Navient notes, however, these commenters often “fail to explain why three calls is an appropriate limit.” Additionally, callers filing comments cite statistics and call patterns documenting their perceived need for more calls—but even callers vary widely when advocating for a number on federal debt collection calls. Congress
27. The Commission determines, subject to the exception below, that a limit of three federal debt collection calls in a thirty-day period is appropriate. As stated above, a significant number of commenters support this numeric restriction. Furthermore, the overwhelming majority of individual commenters support the Commission imposing a low limit on the number of calls allowed pursuant to the Budget Act amendments. Commenters asking for a higher limit have failed to offer a compelling justification for any of the various limits they support. At the same time, the Commission agrees with consumer groups that have noted that callers may make as many calls as they like—they simply need to obtain the consent of the debtor or contact consumers without making a robocall.
28. The Commission, therefore, concludes that the appropriate limit for the number of federal debt collection calls is three calls within thirty days while the delinquency remains or following a specific, time-sensitive event, with such calls also permitted in the 30 days before such an event (but not before delinquency). The Commission recognizes, however, that some federal agencies, based on their expertise administering their respective statutes and programs, may desire additional calls. Balancing these needs with the TCPA's goal of protecting consumers from unwanted calls, the Commission notes that federal agencies may request a waiver seeking a different limit on the number of autodialed, prerecorded-voice, and artificial-voice calls that may be made without consent of the called party. The Commission delegates to the Consumer and Governmental Affairs Bureau the authority to address any such waivers.
29. The Commission is not persuaded by callers who argue that more calls are needed or that other regulatory or contractual obligations might impose higher limits on the total number of calls. The Commission is not limiting the total number of calls that may be made; instead, the Commission is exercising its statutory authority and discretion to establish a limit on the number of autodialed, prerecorded-voice, and artificial-voice calls that can be made without the consent of the called party for the limited purpose at issue here. Thus, the Commission sets this limit with the knowledge that callers may make additional autodialed, artificial-voice, and prerecorded-voice calls if they obtain the prior express consent of the called party or if they dial manually. Robocallers are free, of course, to obtain prior express consent for additional calls and the Commission presumes that consumers who find the calls beneficial will provide it.
30.
31. The Commission also understands that debts may be transferred from one servicer or collector to another. This stop-calling request is specific to the debt and the consumer, and transfers with the debt; once the consumer has asked that the number of federal debt collection calls be reduced to zero, only the consumer can alter that number restriction. Consequently, a stop-calling requests applies to a subsequent collector or servicer of the same debt. In reaching this determination, the Commission rejects a commenter's proposal that a stop-calling request be limited to a period of time such as a month, but be renewable. Because the stop-calling request for federal debt collection calls applies for the life of the debt, servicers and collectors must ensure that information regarding the request conveys with the other relevant information regarding the debt when it is sold or transferred between servicers or collectors. The requirement that the stop-call request conveys from one servicer or collector to the next implicates the Paperwork Reduction Act, as indicated in the Commission's rules, and in the Final Regulatory Flexibility Act.
32. Granting consumers a right to request calls stop at any point is only useful if consumers know of this right. The Commission agrees with the FTC staff that “[a]n opt-out right [] is only effective if it is well-known” rather than with the commenters who argue that a consumer should be notified of the right only once and in writing, or that notifying consumers of the right within every phone call will “cause a consumer to attach undue significance to such a right.” The Commission, therefore, requires callers to inform debtors of their right to make such a request. The disclosure of rights must inform the debtor that he or she has a right to request that no further autodialed, artificial-voice, or prerecorded-voice calls be made to the debtor for the life of the debt, and that such request may be made by any reasonable method. Disclosures must be made in a manner that gives debtors an effective opportunity to stop future calls. Callers must disclose this consumer right within every completed autodialed call with a live caller, whether the caller speaks with the debtor or leaves a voicemail message. Calls using a prerecorded or artificial voice must disclose the right within each message. Covered text messages must disclose the right within each text message or in a separate text message that contains only the disclosure and is sent immediately preceding the first covered text message.
33. The Commission has previously determined that consumers may opt out of calls for which prior consent is required, and that they may do so using any reasonable method, including orally or in response to a text message. Here, where the federal debt collection calls do not require consent, but where consumers may request at any time that calls stop, consumers may also make a stop-calling request using any reasonable method, including orally or in response to a text message. The Commission reaches this conclusion regarding the methods by which a consumer may make a stop-calling request after considering consumer confusion, standard calling practices, and recordkeeping procedures. The Commission anticipates that confusion will be minimized and calling practices will be streamlined if stop-calling methods and opt-out procedures are consistent. For similar reasons, the Commission determines that federal debt collection calls made using a prerecorded or artificial voice must include an automated, interactive voice- and/or key press-activated opt-out mechanism so that debtors who receive these calls may make a stop-calling request during the call by pressing a single key. When a federal debt collection call using an artificial voice or prerecorded voice leaves a voicemail message, that message must also provide a toll-free number that the debtor may call at a later time to connect directly to the automated, interactive voice and/or key press-activated mechanism and automatically record the stop-calling request. Text message disclosures must include brief explanatory instructions for sending a stop-call request by reply text message and provide a toll-free number that enables the debtor to call back later to make a stop-call request. The requirement that the artificial- and prerecorded-voice calls, as well as text messages, include opt-out instructions and features implicates the Paperwork Reduction Act, as indicated in the Commission's rules, and in the Final Regulatory Flexibility Act.
34.
35.
36.
37.
38.
39. The Commission also asked in the
40.
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43. Congress, in authorizing the Commission to enact rules implementing the Budget Act's amendments, stated that the Commission could “restrict or limit the number and duration of calls made to a telephone number assigned to a cellular telephone service.” Congress, by omission, did not authorize the Commission to enact rules to limit the number and duration of calls made to a telephone number assigned to a residential telephone line. Commenters support this understanding of the Budget Act amendment with regard to calls to numbers assigned to residential lines, stating: “Congress did not grant the Commission the authority to restrict or limit” these calls. Consequently, the Commission's current rules regarding non-telemarketing autodialed, prerecorded-voice, and artificial-voice calls to residential numbers are not altered by the Budget Act amendments. The Commission is not imposing restrictions on these calls. Callers may, however, be subject to restrictions under other applicable statutes and regulations, such as the Fair Debt Collection Practices Act.
44.
45. Congress, in granting the Commission authority to limit the number and duration of calls, used identical language to the language it used in the separate delegation of authority in section 227(b)(2)(C) of the Act. The identical language in these two delegations of authority indicates that Congress intended the two provisions to apply to the same services.
46. The Commission has interpreted section 227(b)(2)(C) of the Act to apply to all services mentioned in section 227(b)(1)(A)(iii) of the Act. In so doing, it has interpreted “cellular telephone service” by asking whether services are functionally equivalent from the consumer perspective rather than on technical or regulatory differences, such as which spectrum block is used to provide the service. This avoids, for example, consumers receiving wireless voice service from being treated differently depending on which
47. Applying the canon of statutory construction that Congress knows the law, including relevant agency interpretations, at the time it adopts a statute, the Commission presumes that Congress knew of the Commission's interpretation of this key language. Congress used the same language in the recent delegation of authority without taking any action to alter the Commission's interpretation of identical language elsewhere in the same statute. The Commission therefore concludes that the authority delegated to it in the new section 227(b)(2)(H) of the Act added by the Budget Act applies to all services to which amended section 227(b)(1)(A)(iii) of the Act applies.
48.
49.
50. All of the rules that are adopted in document FCC 16-99 are designed to ensure a caller's ability to make calls pursuant to the Budget Act amendments and a debtor's ability to control the calls he or she receives. Each of the determinations the Commission undertakes in document FCC 16-99 serve a particular function toward this goal. Therefore, it is the Commission's intent that each of the rules and regulations adopted herein shall be severable. The Commission believes that debtors will benefit from the information they may receive from callers and will also benefit from the ability to ask that calls be stopped. If any of the rules or regulations, or portions thereof, are declared invalid or unenforceable for any reason, it is the Commission's intent that the remaining rules shall be in full force and effect.
51. As noted in the discussion above, two portions of the Commission's rules implicate the Paperwork Reduction Act (PRA). These portions involve the rules for the recording of a debtor's request to stop receiving autodialed, artificial-voice, and prerecorded-voice calls to collect a debt owed to or guaranteed by the United States, and rules for the conveyance of that stop-call request from one servicer or collector to another. Because these portions of the rules implicate the PRA, they will not become effective until 60 days after the Commission publishes a Notice in the
52. The remaining rules will not become effective until the rules requiring OMB approval become effective. While these remaining rules do not require OMB approval and could become effective immediately upon release of document FCC 16-99, the Commission determines that the consumer-protection rules regarding stop-call requests and conveyance of those requests are so integral to this regulatory scheme that the remaining rules should not become effective until the consumer-protection rules are in place. The rules that could become effective immediately permit a caller to make calls—they specify how many calls may be made, who may make the calls, when the calls can be made, and to which numbers the calls may be made, among other things. These rules give effect to one of the reasonable interpretations the Commission has identified for Congress' passage of the Budget amendments: to make it easier for owners of debts owed to or guaranteed by the United States and their contractors to make calls to collect debts. But the second reasonable interpretation—to make it easier for consumers to obtain useful information about debt repayment—carries with it a consumer's prerogative to determine that the debtor does not want the information conveyed in the calls and to ask that the calls stop. The rules that give effect to this interpretation of Congress' intent are delayed by PRA requirements and OMB approval. The Commission determines that the regulatory scheme it implements today must include both the ability for callers to make calls and the right of debtors to ask that calls stop—and that both portions of the regulatory scheme become effective simultaneously. To do otherwise would be to allow callers to make calls but to leave debtors with no consumer protections until OMB approval is complete. The Commission determines that both portions of the rules must become effective for the regulatory scheme to be effective.
53. The notice of OMB's approval of the information collections, the announcement of the effective date for the rule changes adopted on August 2, 2016, and released on August 11, 2016, and the appropriate amendatory language, will be contained in a document published in the
54. The amendments to §§ 64.1200(j)(3) and (j)(4) require OMB approval under the Paperwork Reduction Act (PRA) and will not go into effect until 60 days after we publish a notice in the
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55. The Commission determined that the amendments to §§ 64.1200(a)(1)(iii); (a)(3)(iv), (v), and (vi); (f)(17); (i), and (j)(1)-(2),(5)-(9), which do not require OMB approval, nonetheless will not go into effect until 60 days after we publish a notice of OMB approval of § 64.1200(j)(3) and (j)(4), the effective date for all the rule changes, and the amendatory language for the rules. The complete text of the rule changes may be found in the appendix to the Commission's decision, available on the agency Web site. These other rule changes are summarized as follows:
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56. As required by the Regulatory Flexibility Act of 1980 (RFA), as amended, an Initial Regulatory Flexibility Analyses (IRFA) was incorporated into the
57. Document FCC 16-99 promulgates rules to implement section 301 of the Bipartisan Budget Act of 2015, which amends the Telephone Consumer Protection Act by excepting from that Act's consent requirement robocalls to wireless numbers “made solely to collect a debt owed to or guaranteed by the United States” and authorizing the Commission to adopt rules to “restrict or limit the number and duration” of any calls to wireless numbers “to collect a debt owed to or guaranteed by the United States.” The Budget Act requires the Commission, in consultation with the Department of the Treasury, to “prescribe regulations to implement the amendments made” by section 301 of the Budget Act within nine months of enactment. In implementing these provisions, the Commission recognizes and seeks to balance the importance of collecting debt owed to or guaranteed by the United States and the consumer protections inherent in the TCPA. In adopting these rules today, the Commission fulfills the statutory requirement to prescribe rules to implement the amendments to the TCPA.
58.
59. The Commission determines that, because calls made pursuant to the exception must be made “solely to collect a debt,” the covered calls may only be made to the debtor or another person or entity legally responsible for paying the debt. The Commission further determines that covered calls may only be made to the wireless telephone number the debtor provided at the time the debt was incurred, such as on the loan application; to a wireless phone number subsequently provided by the debtor; or to a wireless number that the owner of the debt or its contractor has obtained from an independent source, provided that the number actually is the debtor's telephone number.
60. The Commission determines that robocalls to wrong numbers are not covered by the exception created in the Budget Act amendments. Calls to reassigned wireless numbers may not be made pursuant to the amendment either, but they are subject to the 1-call window the Commission clarified in the
61. The Commission limits eligible callers to the owner of the debt or its contractor. The Commission determines that a “call,” for this exception, includes any initiated call, including a text message. The Commission determines that the excepted calls are limited in content to debt collection and servicing; they may not include any marketing, advertising, or selling products or services, or other irrelevant content.
62.
63. The Commission determines that artificial-voice and prerecorded-voice calls may not exceed 60 seconds, excluding any required disclosures. The Commission does not place any cap on the duration of live-caller, autodialed calls. The Commission limits text messages to 160 characters. Any required disclosures may be included within these 160 characters or may be sent as a separate text message that does not count toward the numeric limits. The Commission determines that no federal debt collection calls or texts are permitted outside the hours of 8:00 a.m. to 9:00 p.m. (local time at the called party's location). The Commission determines that if multiple rules apply to the same call and one of the rules is enacted by the Commission to implement the TCPA, a caller must comply with the most restrictive requirements regarding factors such as frequency, time of day, and so on.
64.
65. In document FCC 16-99, the Commission solicited comments on how to minimize the economic impact of the proposals on small businesses. The Commission received three comments directly addressing the IRFA. Two of the comments addressed the area of duplicate, overlapping, or conflicting rules, and one addressed coordination with the ongoing Consumer Financial Protection Bureau (CFPB) rulemaking. In addition, the Commission received six consumer comments that were against robocalls where the filer mentioned being the owner of a small business. None of the comments pointed out any areas where small businesses would incur a particular hardship in complying with the rules.
66.
67. CMC suggests that the rules conflict with “longstanding federal and state foreclosure prevention efforts and policies”; “several federal requirements to call mortgage borrowers by telephone to try to prevent foreclosures”; “any new FCC rule permitting consumers to block calls”; “[t]he FDCPA prohibit[ion of] unfair practices by debt collectors in attempting to collect a debt”; and “[t]he Dodd-Frank Act prohibit[ion of] unfair, deceptive, or abusive acts or practices by covered persons or service providers, including consumer mortgage servicers.” However, none of the rules cited by CMC require that calls to wireless numbers be autodialed, artificial-voice, or prerecorded-voice calls. The TCPA, with or without the amendments, does not regulate whether or when a debt collector can make a debt collection call, nor does it in any way prohibit a mortgage servicer from making a call in compliance with foreclosure requirements. Debt collectors and mortgage servicers continue to be free to make calls in compliance with non-TCPA law. The rules the Commission adopted apply only to autodialed, prerecorded-voice, and artificial-voice calls. Therefore the rules cited by CMC do not “duplicate, overlap or conflict with” the proposed rule.
68.
69.
70. Pursuant to the Small Business Jobs Act of 2010, which amended the RFA, the Commission is required to respond to any comments filed by the Chief Counsel for Advocacy of the Small Business Administration (SBA), and to provide a detailed statement of any change made to the proposed rules as a result of those comments. The Chief Counsel did not file any comments in response to the proposed rules in this proceeding.
71. The RFA directs agencies to provide a description of, and where feasible, an estimate of the number of small entities that may be affected by the rules adopted herein. The RFA generally defines the term “small entity” as having the same meaning as the terms “small business,” “small organization,” and “small governmental jurisdiction.” In addition, the term “small business” has the same meaning as the term “small-business concern” under the Small Business Act. A “small-business concern” is one which: (1) Is independently owned and operated; (2) is not dominant in its field of operation; and (3) satisfies any additional criteria established by the SBA.
72. The Commission's rules restricting autodialed, artificial-voice, and prerecorded-voice calls to wireless numbers apply to all entities that make such calls or texts to wireless telephone numbers to collect debts owed to or guaranteed by the United States. Thus, the rules set forth in this proceeding are likely to have an impact on a substantial number of small entities in several categories.
73.
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86. Document FCC 16-99 amends the Commission's rules implementing the TCPA to align them with the amended statutory language of the TCPA enacted by Congress in the 2015 Budget Act, creating an exception that allows the use of an autodialer, prerecorded-voice, and artificial-voice when making calls to wireless telephone numbers without the prior express consent of the called party when such calls are made solely to collect a debt owed to or guaranteed by the United States, and imposing limitations on autodialed, prerecorded-voice, and artificial-voice calls to collect a debt owed to or guaranteed by the United States. Document FCC 16-99 will likely impose a one-time cost on some entities to set up new recordkeeping and other compliance requirements. These changes affect small and large companies equally, and apply equally to all of the classes of regulated entities identified above.
87. To comply with the right of the consumer to stop autodialed, artificial-voice, and prerecorded-voice federal debt collection calls to wireless numbers without consent, regulated entities must keep a record of any request made by a consumer for the cessation of the calls, and must pass that information to any subsequent collector or servicer of the debt if the debt is transferred. This rule obligates callers to retain records of consumers opting out of receiving these autodialed or prerecorded federal debt collection messages. Because autodialed, artificial-voice, and prerecorded-voice federal debt collection calls to wireless numbers required consent prior to these amendments, the Commission assumes calling entities have systems and procedures already in place to record consent and that the current way of doing business will be sufficient for tracking revocation of consent and will not impose new costs. However, the requirement to inform subsequent collectors or servicers of the revocation of consent might be new for some calling entities, and could impose a small initial cost to modify systems or procedures. This provision does not impose a significant economic impact on small businesses. The Commission did not receive any comments stating that this rule would cause a significant economic impact on small businesses. The Commission does not require a particular form or format to be used in conveying the revocation of consent to subsequent collectors or servicers when a debt is transferred.
88. Federal debt collection calls made using a prerecorded or artificial voice must include an automated, interactive voice- and/or key press-activated opt-out mechanism so that debtors who receive these calls may make a stop-calling request during the call by pressing a single key. When a federal debt collection call using an artificial voice or prerecorded voice leaves a voicemail message, that message must also provide a toll-free number that the debtor may call at a later time to connect directly to the automated, interactive voice and/or key press-activated mechanism and automatically record the stop-calling request. Text message disclosures must include brief explanatory instructions for sending a stop-call request by reply text message and provide a toll-free number that enables the debtor to call back later to make a stop-call request. This rule obligates callers to modify their systems to produce the message, maintain toll-free numbers, and record any stop-call requests. Such records should demonstrate the caller's compliance with the provision and utilization of the automated, interactive opt-out feature. The Commission allows the calling entities the flexibility to determine how to implement the mechanism. The Commission does not require a particular form or format evidencing this mechanism or its implementation. This provision does not impose a significant economic impact on small businesses. The Commission did not receive any comments stating that this rule would cause a significant economic impact on small businesses.
89. The RFA requires an agency to describe any significant alternatives that it has considered in reaching its approach, which may include the following four alternatives, among others: (1) The establishment of differing compliance or reporting requirements or timetables that take into account the resources available to small entities; (2) the clarification, consolidation, or simplification of compliance or reporting requirements under the rule for small entities; (3) the use of performance, rather than design, standards; and (4) an exemption from coverage of the rule, or any part thereof, for small entities.
90. The amendments to the rules change the specific conditions under which a caller can use an autodialer, prerecorded voice, and artificial voice to make calls to a wireless number without the prior express consent of the called party and the limitations that apply to autodialed, prerecorded-voice, and artificial-voice calls to a wireless number made to collect a debt owed to or guaranteed by the United States. The limitations balance the importance of collecting debt owed to the United States and the consumer protections inherent in the TCPA. The Commission interprets the amendments as allowing such calls to be made by the federal government, owners of debt guaranteed by the federal government, and by their respective contractors. The amendments therefore benefit the federal government, owners of debt guaranteed by the federal government, and their respective contractors. Although the federal government is not a small business, many of the owners of debt guaranteed by the federal government and the contractors who make these calls are small businesses. Thus, the Commission considered the needs of small businesses in reaching its approach.
91. Automated dialers and artificial-voice, and prerecorded-voice calling systems can be used to make thousands of calls without requiring commensurate staffing. By automating the process of making calls and texts, small businesses can make as many calls as large businesses. The volume of calls is not limited by the size of the business. Therefore limitations designed to protect consumer interests must apply to both large and small calling entities to be effective. The Commission believes that any economic burden these proposed rules may have on callers is outweighed by the benefits to consumers.
92.
93.
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95.
The Commission will send a copy of document FCC 16-99 to Congress and the Government Accountability Office pursuant to the Congressional Review Act, see 5 U.S.C. 801(a)(1)(A).
Document FCC 16-99 contains modified information collection requirements. The Commission, as part of its continuing effort to reduce paperwork burdens, will invite the general public to comment on the information collection requirements contained in document FCC 16-99 as required by the Paperwork Reduction Act (PRA) of 1995, Public Law 104-13. In addition, the Commission notes that, pursuant to the Small Business Paperwork Relief Act of 2002, Public Law 107-198, 44 U.S.C. 3506(c)(4), the Commission previously sought comment on how the Commission might “further reduce the information burden for small business concerns with fewer than 25 employees.” See Rules and Regulations Implementing the Telephone Consumer Protection Act of 1991, Notice of Proposed Rulemaking, published at 81 FR 31889, May 20, 2016 (2016 NPRM).
Claims, Communications common carriers, Credit, Reporting and recordkeeping requirements, Telecommunications, and Telephone.
Department of the Treasury.
Final rule.
This final rule amends the Department of Treasury Acquisition Regulation (DTAR) for the purposes of providing acquisition policy for incremental funding of Fixed-Price, Time-and-Material or Labor-Hour contracts during a continuing resolution.
Thomas O'Linn, Procurement Analyst, Office of the Procurement Executive, at (202) 622-2092.
The DTAR, which supplements the Federal Acquisition Regulation (FAR), is codified at 48 CFR Chapter 10.
The Anti-Deficiency Act, 31 U.S.C. 1341 and the FAR section 32.702, state that no officer or employee of the government may create or authorize an obligation in excess of the funds available, or in advance of appropriations unless otherwise authorized by law. A continuing resolution (CR) provides funding for continuing projects or activities that were conducted in the prior fiscal year for which appropriations, funds, or other authority was previously made available.
Each CR is governed by its specific terms. However, amounts available under a CR are frequently insufficient to fully fund contract actions that may be required during its term. No existing contract clause permits partial funding of a contract action awarded during a CR. While other strategies are available to address the need to take contract actions during a CR, these strategies—for example short-term awards—are inefficient and may have other disadvantages.
On July 12, 2016, the Department issued a proposed rule (81 FR 45118) that would establish policies and procedures in order to facilitate successful, timely, and economical execution of Treasury contractual actions during a CR. Specifically, the proposed rule would set forth procedures for using incremental funding for fixed-price, time-and-material and labor-hour contracts during a period in which funds are provided to Treasury Departmental Offices or Bureaus under a CR. Heads of contracting activities may develop necessary supplemental internal procedures as well as guidance to advise potential offerors, offerors and contractors of these policies and procedures.
The comment period for the proposed rule closed on September 12, 2016. No public comments were received. Accordingly, the Department is adopting the proposed rule without substantive change.
This rule is not a significant regulatory action as defined in section 3(f) of Executive Order 12866. Therefore a regulatory assessment is not required.
The Regulatory Flexibility Act (5 U.S.C. chapter 6) generally requires agencies to conduct an initial regulatory flexibility analysis and a final regulatory flexibility analysis of any rule subject to notice and comment rulemaking requirements, unless the agency certifies that the rule will not have a significant economic impact on a substantial number of small entities.
It is hereby certified that this rule will not have a significant economic impact on a substantial number of small entities. The rule is intended to make changes to the DTAR that would allow for improvements in continuity when Treasury funding is operating under a CR and should not have significant economic impacts on small entities.
Government procurement.
Accordingly, the Department of the Treasury amends 48 CFR Chapter 10 as follows:
41 U.S.C. 1707.
This section provides policy and procedure for using incremental funding for fixed-price, time-and-material and labor-hour contracts during a period in which funds are provided to Treasury Departmental Offices or Bureaus, under a continuing resolution (CR). HCAs may develop necessary supplemental internal procedures as well as guidance to advise potential offerors, offerors and contractors of these policies and procedures. Additionally, Bureaus who receive non-appropriated funds may utilize and tailor these policies and procedures to fit their needs.
“Continuing Resolution” means an appropriation, in the form of a joint resolution, that provides budget authority for federal agencies, specific activities, or both to continue operation until the regular appropriations are enacted. Typically, a continuing resolution is used when legislative action on appropriations is not completed by the beginning of a fiscal year.
The Anti-Deficiency Act, 31 U.S.C. 1341 and FAR 32.702, states that no officer or employee of the Government may create or authorize an obligation in excess of the funds available, or in advance of appropriations unless otherwise authorized by law. A CR provides funding for continuing projects or activities that were conducted in the prior fiscal year for which appropriations, funds, or other authority was previously made available. Each CR is governed by the specific terms in that specific CR (
(a) A fixed-price, time-and-materials or labor-hour contract or order for commercial or non-commercial supplies or severable or non-severable services may be incrementally funded when—
(1) Funds are provided to a Treasury Departmental Office or Bureau under a CR. This includes funds appropriated to a bureau, funds appropriated to another entity that will be directly obligated on a Treasury contract, and funds in a revolving fund or similar account that will be reimbursed by a customer agency funded by a CR;
(2) Sufficient funds are not being allocated from the responsible fiscal authority to fully fund the contract action that is otherwise authorized to be issued;
(3) There is no statutory restriction that would preclude the proposed use of funds;
(4) Funds are available and unexpired, as of the date the funds are obligated;
(5) Assurance is provided by the responsible financial authority that full funding is anticipated once an Appropriation Act is enacted; and
(6) The clause prescribed by 1032.770-7 is incorporated into the contract or order.
(b) Incremental funding may be limited to individual line item(s) or a particular order(s).
(a) This policy does not apply to contract actions that are not covered by the CR.
(b) If this policy is applied to non-severable services or to supplies, the contracting officer shall take into consideration the business risk to the Government if funding does not become available to fully fund the contract. If the contracting officer determines the use of incremental funding for non-severable services or supplies is in the best interest of the Government the contracting officer shall ensure the contractor fully understands how the limitations of the Government's liabilities under the contract might impact its ability to perform within the prescribed contract schedule.
(a) An incrementally funded fixed-price, time-and-materials or labor-hour contract shall be fully funded once funds are available.
(b) The contracting officer shall ensure that sufficient funds are allotted to the contract to cover the total amount payable to the contractor in the event of termination of convenience by the Government.
(c) Upon receipt of the contractor's notice under paragraph (c) of the clause at 1052.232-90, Limitation of Government's Obligation, the contracting officer shall promptly provide written notice to the contractor that the Government is—
(i) Obligating additional funds for continued performance and increasing the Government's limitation of obligation in a specified amount;
(ii) Obligating the full amount of funds needed;
(iii) Terminating for convenience, as applicable, the affected line items or contract; or
(iv) Considering whether to allot additional funds; and
(A) The contractor is entitled by the contract terms to stop work when the Government's limitation of obligation is reached; and
(B) Any costs expended beyond the Government's limitation of obligation are at the contractor's risk.
(d) Upon learning that the contract will receive no further funds by the date provided in the notice under paragraph (c) of the clause at 1052.232-70, Limitation of Government's Obligation, the contracting officer shall promptly give the contractor written notice of the Government's decision and terminate the affected line items or contract, as applicable, for the convenience of the Government.
The contracting officer shall insert the clause at 1052.232-70, Limitation of Government's Obligation, in
(a) Solicitations and resultant contracts when incremental funding of fixed-price, time-and-material or labor-hour contract via a CR is anticipated; or
(b) Contracts or orders when incremental funding of a fixed-price, time-and-material or labor-hour contract is authorized and the Treasury Departmental Office or Bureau is operating under a CR (see 1032.770-4); and
(c) The CO shall insert the information required in paragraphs (a) and (c) of the clause.
41 U.S.C. 1707.
As prescribed in 1032.770-7, insert the following clause. Contracting
(a) Funding is not currently available to fully fund this contract due to the Government operating under a continuing resolution (CR). The item(s) listed in the table below are being incrementally funded as described below. The funding allotted to these item(s) is presently available for payment and allotted to this contract. This table will be updated by a modification to the contract when additional funds are made available, if any, to this contract.
(b) For the incrementally funded item(s) identified in paragraph (a) of this clause, the Contractor agrees to perform up to the point at which the total amount payable by the Government, including any invoice payments to which the Contractor is entitled and reimbursement of authorized termination costs in the event of termination of those item(s) for the Government's convenience, does not exceed the total amount currently obligated to those item(s). The Contractor is not authorized to continue work on these item(s) beyond that point. The Government will not be obligated in any event to reimburse the Contractor in excess of the amount allotted to the line items of the contract regardless of anything to the contrary in any other clause, including but not limited to the clause entitled “Termination for Convenience of the Government” or paragraph (1) entitled “Termination for the Government's Convenience” of the clause at FAR 52.212-4, “Commercial Terms and Conditions Commercial Items.”
(c) Notwithstanding paragraph (h) of this clause, the Contractor shall notify the Contracting Officer in writing at least thirty days prior to the date when, in the Contractor's best judgment, the work will reach the point at which the total amount payable by the Government, including any cost for termination for convenience, will approximate 85 percent of the total amount then allotted to the contract for performance of the item(s) identified in paragraph (a) of this clause. The notification shall state the estimated date when that point will be reached and an estimate of additional funding, if any, needed to continue performance. The notification shall also advise the Contracting Officer of the estimated amount of additional funds required for the timely performance of the item(s) funded pursuant to this contract. If after such notification additional funds are not allotted by the date identified in the Contractor's notification, or by an agreed upon substitute date, the Contracting Officer will terminate any item(s) for which additional funds have not been allotted, pursuant to the terms of this contract authorizing termination for the convenience of the Government. Failure to make the notification required by this paragraph, whether for reasons within or beyond the Contractor's control, will not increase the maximum amount payable to the Contractor under paragraphs (a) and (b) of this clause.
(d) The Government may at any time prior to termination allot additional funds for the performance of the item(s) identified in paragraph (a) of this clause.
(e) The termination provisions of paragraphs (a) through (h) of this clause do not limit the rights of the Government under the clause entitled “Default” or “Termination for Cause.” The provisions of this clause are limited to the work and allotment of funds for the item(s) set forth in paragraph (a) of this clause. This clause no longer applies once the contract is fully funded.
(f) Nothing in this clause affects the right of the Government to terminate this contract pursuant to the Government's termination for convenience terms set forth in this contract.
(g) Nothing in this clause shall be construed as authorization of voluntary services whose acceptance is otherwise prohibited under 31 U.S.C. 1342.
(h) The parties contemplate that the Government will allot funds to this contract from time to time as the need arises and as funds become available. There is no fixed schedule for providing additional funds.
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Temporary rule; modification of a closure.
NMFS is opening directed fishing for Pacific cod by catcher/processors using pot gear in the Bering Sea and Aleutian Islands Management Area (BSAI). This action is necessary to fully use the 2016 total allowable catch of Pacific cod allocated to catcher/processors using pot gear in the BSAI.
Effective 1200 hours, Alaska local time (A.l.t.), November 15, 2016, through 2400 hours, A.l.t., December 31, 2016. Comments must be received at the following address no later than 4:30 p.m., A.l.t., December 1, 2016.
You may submit comments on this document, identified by NOAA-NMFS-2015-0118, by any of the following methods:
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Josh Keaton, 907-586-7228.
NMFS manages the groundfish fishery in the BSAI exclusive economic zone according to the Fishery Management Plan for Groundfish of the Bering Sea and Aleutian Islands Management Area (FMP) prepared by the North Pacific Fishery Management Council under authority of the Magnuson-Stevens Fishery Conservation and Management Act. Regulations governing fishing by U.S. vessels in accordance with the FMP appear at subpart H of 50 CFR part 600 and 50 CFR part 679.
NMFS closed directed fishing for Pacific cod by catcher/processors using pot gear in the BSAI under § 679.20(d)(1)(iii) on October 18, 2016 (81 FR 72009, October 19, 2016).
NMFS has determined that as of November 7, 2016, approximately 2,000 metric tons of Pacific cod remain in the 2016 Pacific cod apportionment for catcher/processors using pot gear in the BSAI. Therefore, in accordance with § 679.25(a)(1)(i), (a)(2)(i)(C), and (a)(2)(iii)(D), and to fully use the 2016 total allowable catch (TAC) of Pacific cod in the BSAI, NMFS is terminating the previous closure and is opening directed fishing for Pacific cod by catcher/processors using pot gear in the BSAI. The Administrator, Alaska Region, NMFS, (Regional Administrator) considered the following factors in reaching this decision: (1) The current catch of Pacific cod by catcher/processors using pot gear in the BSAI and, (2) the harvest capacity and stated intent on future harvesting patterns of vessels in participating in this fishery.
This action responds to the best available information recently obtained from the fishery. The Assistant Administrator for Fisheries, NOAA (AA), finds good cause to waive the requirement to provide prior notice and opportunity for public comment pursuant to the authority set forth at 5 U.S.C. 553(b)(B) as such requirement is impracticable and contrary to the public interest. This requirement is impracticable and contrary to the public interest as it would prevent NMFS from responding to the most recent fisheries data in a timely fashion and would delay the opening of directed fishing for Pacific cod by catcher/processors using pot gear in the BSAI. Immediate notification is necessary to allow for the orderly conduct and efficient operation of this fishery, to allow the industry to plan for the fishing season, and to avoid potential disruption to the fishing fleet and processors. NMFS was unable to publish a notice providing time for public comment because the most recent, relevant data only became available as of November 7, 2016.
The AA also finds good cause to waive the 30-day delay in the effective date of this action under 5 U.S.C. 553(d)(3). This finding is based upon the reasons provided above for waiver of prior notice and opportunity for public comment.
Without this inseason adjustment, NMFS could not allow the fishery for Pacific cod by catcher/processors using pot gear in the BSAI to be harvested in an expedient manner and in accordance with the regulatory schedule. Under § 679.25(c)(2), interested persons are invited to submit written comments on this action to the above address until December 1, 2016.
This action is required by § 679.25 and is exempt from review under Executive Order 12866.
16 U.S.C. 1801
Department of Energy.
Notice of proposed rulemaking and public hearings.
The Department of Energy (DOE or Department) proposes to revise its regulations governing the standards for safeguarding Restricted Data by access permittees. The existing version of this regulation was promulgated in 1983, which transferred the regulation (originally promulgated in 1976). Since 1983, changes in organizations, terminology, and DOE and national policies render portions of the existing regulation outdated. The proposed revisions would update existing requirements.
Written comments must be received by DOE on or before December 16, 2016.
A public meeting will be held if one is requested by November 23, 2016.
Written comments should be addressed to: Mr. Matthew B. Moury, Associate Under Secretary for Environment, Health, Safety and Security, Office of Environment, Health, Safety and Security, AU-1/Forrestal Building, Department of Energy, Docket No. DOE-HQ-2015-0029-0001, 1000 Independence Avenue SW., Washington, DC 20585 or via email at
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As a result of potential delays in the receipt and processing of mail sent through the U.S. Postal Service, DOE encourages respondents to submit comments electronically to ensure timely receipt.
Ms. Linda Ruhnow, Office of Security Policy at (301) 903-4053;
The U.S. Department of Energy may issue an access permit to any person, as set forth in 10 CFR part 725, who requires access to Restricted Data applicable to civil uses of atomic energy for use in his/her business, trade or profession. 10 CFR part 725 specifies the terms and conditions under which the Department will issue an access permit and provides for the amendment, renewal, suspension, termination and revocation of an access permit.
The regulations in 10 CFR part 1016 establish requirements for the safeguarding of Secret and Confidential Restricted Data received or developed under an access permit. This part does not apply to Top Secret information because no such information may be provided to an access permittee within the scope of this regulation. The regulations in this part apply to all persons who may require access to Restricted Data used, processed, stored, reproduced, transmitted, or handled in connection with an access permit.
The original regulations for the safeguarding of Restricted Data were Atomic Energy Commission regulations that were transferred to the Energy Research and Development Administration (ERDA) upon its formation in 1974 (Energy Reorganization Act of 1974; Pub. L. 93-438). The regulations were subsequently revised to conform to ERDA's organization (41 FR 56775, 56785-56788, Dec. 30, 1976). The regulations were updated and transferred from 10 CFR part 795 to 10 CFR part 1016 in 1983. (48 FR 36432 (Aug. 10, 1983). DOE has developed the proposed modifications to 10 CFR part 1016 to reflect organizational, terminology and policy changes that have occurred since the regulations were last revised.
The proposed modifications to the sections of 10 CFR part 1016 that DOE proposes to amend are described in the Section by Section Analysis in section II.
The heading for this part would be revised to
In § 1016.3, Definitions, DOE proposes to delete the term “Authorized classifier”. Instead, 10 CFR part 1045 would be referenced as the source of classification requirements.
The terms “Document”, “Material” and “Matter” would be deleted because they are not used in any unique way in this regulation.
The access authorization terms Q, Q(X), L and L(X) would be updated to specify the type of background investigation required. For example, single scope background investigations are required for Q access authorizations.
The term “classified mail address” would be revised for better grammar.
The term “classified matter” would be revised to include all documents, material, electronic media and other physical forms that reveal or contain classified information.
The term “infraction” would be revised to include non-compliance with DOE approvals.
The term “intrusion alarm” would be revised to “intrusion detection system” and updated for more accurate usage consistent with current DOE policy.
The term “National Security Information” would be revised for consistency with Executive Order 13526,
The term “Security Plan” would be revised to clarify that matter refers to classified matter.
Proposed changes for § 1016.4 would revise the addressee from the “Chief Health, Safety and Security Officer”, to the “Associate Under Secretary of Environment, Health, Safety and Security” to address a recent reorganization.
Proposed changes for § 1016.5 would require that procedures submitted pursuant to this section ensure that access permit holder employees are informed about classification and declassification requirements in 10 CFR part 1045.
DOE proposes to change the title of § 1016.8 to clarify the section topic.
The proposed changes for § 1016.9 and § 1016.10 revise grammar.
The proposed changes for § 1016.11 would revise “DOE Operations Office” to “the cognizant DOE office” to direct notification to the relevant DOE Element.
The proposed changes for § 1016.12 would update reference to reflect the proposed renumbering of current § 1016.39.
DOE proposes to renumber §§ 1016.21—1016.44 to eliminate the gaps in section numbering that exist in the current version of this regulation.
The renumbered § 1016.13, currently § 1016.21, would be revised to maintain consistency with current national and U.S. Department of Energy policies that no longer allows storage of classified matter in a locked steel file cabinet.
Proposed changes to the renumbered § 1016.14, currently § 1016.22, would clarify that a person must have need-to-know in addition to the appropriate access authorization. This revision does not change the intent of the requirement for protecting Restricted Data that is in use.
Proposed changes to the renumbered § 1016.15, currently § 1016.23, would update intrusion detection system terminology consistent with DOE policy and delete the word “may”.
Proposed changes to the renumbered § 1016.17, currently § 1016.25, would update the weapon specification to match current DOE policy. DOE Order 473.3, Protection Program Operations lists DOE-authorized firearms.
Proposed changes to the renumbered § 1016.18, currently § 1016.31, would apply the need-to-know criterion for Confidential as well as Secret Restricted Data.
Proposed changes to the renumbered § 1016.19, currently § 1016.32, would align requirements and terminology with 10 CFR part 1045,
Proposed changes to the renumbered § 1016.20, currently § 1016.33, would specify need-to-know as a basic criteria for determining access; indicate required approvals and remove the telephone statement because it is a subset of the telecommunication statement.
Proposed changes to the renumbered § 1016.21, currently § 1016.34, would reflect that classified matter (including matter in electronic format) containing Secret Restricted Data requires accountability.
Proposed changes to the renumbered § 1016.23, currently § 1016.36, would make changes in classification subject to the requirements in 10 CFR part 1045,
Proposed changes to the renumbered § 1016.24, currently § 1016.37, would amend the title to replace “documents or material” with “classified matter” and would delete provisions that are duplicative with the renumbered § 1016.21 regarding accountability of classified matter that contains Restricted Data.
Proposed new § 1016.25, Storage, use, processing, transmission and destruction of classified information on computers, computer networks, electronic devices/media, and mobile devices, would be added to include additional direction regarding newer forms of media (electronic) that may contain Restricted Data.
Proposed changes to the renumbered § 1016.27, currently § 1016.39 would clarify that termination of the security facility approval will be in accordance with the requirements in this part.
Proposed changes to the renumbered § 1016.31, currently § 1016.43, would update the reference to Executive Order 13526.
Throughout the proposed changes, the term “classified matter” is used so as to include documents and material.
This action does not constitute a “significant regulatory action” as defined in section 3(f) of Executive Order 12866, “Regulatory Planning and Review” (58 FR 51735).
The Regulatory Flexibility Act (5 U.S.C. 601
DOE has reviewed this proposed rule under the Regulatory Flexibility Act and certifies that, if adopted, the rule would not have a significant impact on a substantial number of small entities. This proposed action would amend an existing rule which establishes
Because these standards and requirements consist of clarifications and updates to existing standards and requirements, DOE does not expect that the impact on any Access Permittees would be significant. DOE seeks comment on its estimate of the number of small entities and the expected effects of this proposed rule.
For the above reasons, DOE certifies that the proposed rule, if adopted, will not have a significant economic impact on a substantial number of small entities.
This proposed rule does not contain a collection of information subject to OMB approval under the Paperwork Reduction Act.
This proposed rule amends existing policies and procedures establishing safeguarding of Restricted Data standards and requirements for Access Permittees and has no significant environmental impact. Consequently, the Department has determined that this rule is covered under Categorical Exclusion A-5, of Appendix A to Subpart D, 10 CFR part 1021, which applies to a rulemaking that addresses amending an existing rule or regulation that does not change the environmental effect of the rule or regulation being amended. Accordingly, neither an environmental assessment nor an environmental impact statement is required.
Executive Order 13132, “Federalism,” (64 FR 43255, August 4, 1999), imposes certain requirements on agencies formulating and implementing policies or regulations that preempt State law or that have federalism implications. Agencies are required to develop a formal process to ensure meaningful and timely input by State and local officials in the development of regulatory policies that have “federalism implications.” Policies that have federalism implications are defined in the Executive Order to include regulations that have “substantial direct effects on the States, on the relationship between the national government and the States, or on the distribution of power and responsibilities among the various levels of government.” On March 7, 2011, DOE published a statement of policy describing the intergovernmental consultation process it will follow in the development of such regulations (65 FR 13735, March 14, 2000).
DOE has examined the proposed and revised rule and has determined that it does not have a substantial direct effect on the States, on the relationship between the national government and the States, or on the distribution of power and responsibilities among the various levels of government. No further action is required by Executive Order 13132.
Section 3 of Executive Order 12988, (61 FR 4729, February 7, 1996), instructs each agency to adhere to certain requirements in promulgating new regulations. These requirements, set forth in section 3(a) and (b), include eliminating drafting errors and needless ambiguity, drafting the regulations to minimize litigation, providing clear and certain legal standards for affected legal conduct, and promoting simplification and burden reduction. Agencies are also instructed to make every reasonable effort to ensure that the regulation describes any administrative proceeding to be available prior to judicial review and any provisions for the exhaustion of administrative remedies. The Department has determined that this regulatory action meets the requirements of section 3(a) and (b) of Executive Order 12988.
Title II of the Unfunded Mandates Reform Act of 1995 (UMRA) requires each Federal agency to assess the effects of Federal regulatory action on state, local and tribal governments and the private sector. For proposed regulatory actions likely to result in a rule that may cause expenditures by State, local, and Tribal governments, in the aggregate, or by the private sector of $100 million or more in any one year (adjusted annually for inflation), section 202 of UMRA requires a Federal agency to publish estimates of the resulting costs, benefits, and other effects on the national economy. UMRA also requires Federal agencies to develop an effective process to permit timely input by elected officers of State, local, and Tribal governments on a proposed “significant intergovernmental mandate.” In addition, UMRA requires an agency plan for giving notice and opportunity for timely input to small governments that may be affected before establishing a requirement that might significantly or uniquely affect them. On March 18, 1997, DOE published a statement of policy on its process for intergovernmental consultation under UMRA (62 FR 12820, March 18, 1997). (This policy is also available at
Executive Order 13211, “Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use,” (66 FR 28355, May 22, 2001) requires Federal agencies to prepare and submit to the Office of Information and Regulatory Affairs (OIRA), Office of Management and Budget, a Statement of Energy Effects for any proposed significant energy action. A “significant energy action” is defined as any action by an agency that promulgates or is expected to lead to the promulgation of a final rule, and that: (1) Is a significant regulatory action under Executive Order 12866, or any successor order; and (2) is likely to have a significant adverse effect on the supply, distribution, or use of energy; or (3) is designated by the Administrator of OIRA as a significant energy action. For any proposed significant energy action, the agency must give a detailed statement of any adverse effects on energy supply, distribution, or use should the proposal be implemented, and of reasonable alternates to the action and their expected benefits on energy supply, distribution, and use.
This proposed rule is not a significant energy action, nor has it been designated as such by the Administrator of OIRA. Accordingly, DOE has not prepared a Statement of Energy Effects.
Section 654 of the Treasury and General Government Appropriations Act, 1999 (Pub. L. 105-277) requires Federal agencies to issue a Family Policymaking Assessment for any proposed rule or policy that may affect family well-being. This proposed rule would not have any impact on the autonomy or integrity of the family as
DOE encourages the maximum level of public participation in this rulemaking. Interested persons are encouraged to participate in the public hearings at the times and places indicated at the beginning of this proposed rulemaking.
DOE has established a period of thirty days following publication of this proposed rulemaking for persons and organizations to comment. All public comments, hearing transcripts, and other docket material will be available for review and copying at the DOE offices at each of the hearing sites. The docket material will be filed under “DOE-HQ-2015-0029-0001.”
Interested persons are invited to participate in this proceeding by submitting written data, views or arguments with respect to the subjects set forth in this proposed rulemaking. Instructions for submitting written comments are set forth at the beginning of this notice and below. Where possible, comments should identify the specific section they address.
Comments should be labeled both on the envelope and on the documents, “Docket No. DOE-HQ-2015-0029-0001” and must be received by the date specified at the beginning of this proposed rulemaking. All comments and other relevant information received by the date specified at the beginning of this proposed rulemaking will be considered by DOE in the subsequent stages of the rulemaking process.
Pursuant to the provisions of 10 CFR part 1004, any person submitting information or data that is believed to be confidential and exempt by law from public disclosure should submit one complete copy of the document and three copies, if possible, from which the information believed to be confidential has been deleted. DOE will make its own determination with regard to the confidential status of the information or data and treat it according to its determination.
The dates, times and places of the public hearings are indicated at the beginning of this proposed rulemaking. DOE invites any person or organization who has an interest in these proceedings to make a request to make an oral presentation at one of the public hearings. Requests can be phoned in advance to the telephone number indicated at the beginning of this proposed rulemaking. The person making the request should provide a telephone number where he or she may be contacted.
DOE reserves the right to schedule the presentations, and to establish the procedures governing the conduct of the hearings.
A DOE official will be designated to preside at the hearings and ask questions. Any necessary procedural rules regarding proper conduct of the hearings will be determined by the presiding official.
Transcripts of the hearings will be made and the entire record of this rulemaking, including the transcripts, will be retained by DOE and made available for inspection and copying as provided at the beginning of this proposed rulemaking as well as being posted on
Classified information, Nuclear energy, Reporting and recordkeeping requirements, Security measures.
For the reasons set out in the preamble, DOE proposes to amend part 1016 of title 10 of the Code of Federal Regulations as set forth below:
Sec. 161i of the Atomic Energy Act of 1954, 68 Stat. 948 (42 U.S.C. 2201).
The revisions read as follows:
(a)
(1) “Q” access authorizations are based upon single scope background investigations as set forth in applicable DOE and national-level directives. They permit an individual who has “need to know” access to Top Secret, Secret and Confidential Restricted Data, Formerly Restricted Data, National Security Information, or special nuclear material in Category I or II quantities as required in the performance of duties, subject to additional determination that permitting this access will not endanger the common defense or national security of the United States. There may be additional requirements for access to specific types of RD information.
(2) “Q(X)” access authorizations are based upon the same level of investigation required for a Q access authorization when “Q” access authorizations are granted to access permittees they are identified as “Q(X)” access authorizations and, as need-to-know applies, authorize access only to the type of Secret Restricted Data as specified in the permit and consistent with appendix A, 10 CFR part 725, “Categories of Restricted Data Available.”
(3) “L” access authorizations are based upon National Agency Check with Local Agency Checks and Credit Check background investigation as set forth in applicable DOE and national-level directives. They permit an individual who has “need to know” access to Confidential Restricted Data, Secret and Confidential Formerly Restricted Data, or Secret and Confidential National Security Information, required in the performance of duties, provided such information is not designated
(4) “L(X)” access authorizations are based upon the same level of investigation required for an L access authorization When “L” access authorizations are granted to access permittees, they are identified as “L(X)” access authorizations and, as need to know applies, authorize access only to the type of Confidential Restricted Data as specified in the permit and consistent with appendix A, 10 CFR part 725, “Categories of Restricted Data Available.”
(c)
(d)
(h)
(i)
(k)
(u)
Communications concerning rulemaking,
No access permit holder shall have access to Restricted Data until he has submitted to the DOE a written statement of his procedures for the safeguarding of Restricted Data and for the security education of his employees, and DOE shall have determined and informed the permittee that his procedures for the safeguarding of Restricted Data are in compliance with the regulations in this part and that his procedures for the security education of his employees, who will have access to Restricted Data, are informed about and understand the regulations in this part. These procedures must ensure that employees with access to Restricted Data are informed about and understand who is authorized or required to classify and declassify RD and FRD information and classified matter as well as how documents containing RD or FRD are marked (see 10 CFR part 1045) and safeguarded.
Following receipt of an acceptable request for security facility approval, the DOE will perform an initial security survey of the permittee's facility to determine that granting a security facility approval would be consistent with the national security. If DOE makes such a determination, security facility approval will be granted. If not, security facility approval will be withheld pending compliance with the security survey recommendations or until a waiver is granted pursuant to § 1016.6 of this part.
Notification of the DOE's granting, denial, or suspension of security facility approval will be furnished the permittee in writing, or orally with written confirmation. This information may also be furnished to representatives of the DOE, DOE contractors, or other Federal agencies having a need to transmit Restricted Data to the permittee.
When a request for security facility approval is to be withdrawn or cancelled, the cognizant DOE Office will be notified by the requester immediately by telephone and confirmed in writing so that processing of this approval may be terminated.
Security facility approval will be terminated when:
(a) There is no longer a need to use, process, store, reproduce, transmit, or handle Restricted Data at the facility; or
(b) The DOE makes a determination that continued security facility approval is not in the interest of common defense and security.
The permittee will be notified in writing of a determination to terminate facility approval, and the procedures outlined in § 1016.27 of this part will apply.
(a) Persons who possess Restricted Data pursuant to an Access Permit shall store the Restricted Data classified matter when not in use in a locked storage container or DOE-approved vault to which only persons with appropriate access authorization and a need to know the information contained have access. Storage containers used for storing classified matter must conform to U.S. General Services Administration (GSA) standards and specifications.
(b) Changes of combination: Each permittee shall change the combination on locks of his safekeeping equipment whenever such equipment is placed in use, whenever an individual knowing the combination no longer requires access to the repository as a result of change in duties or position in the permittee's organization, or termination of employment with the permittee or whenever the combination has been subjected to compromise, and in any event at least once a year. Permittees shall classify records of combinations no lower than the highest classification of the classified matter authorized for storage in the safekeeping equipment concerned.
While in use, classified matter containing Restricted Data shall be under the direct control of a person with the appropriate access authorization and need to know. Unauthorized access to the Restricted Data shall be precluded.
(a) When, because of their nature or size, it is impracticable to safeguard classified matter containing Restricted Data in accordance with the provisions of §§ 1016.13 and 1016.14, a security area to protect such classified matter shall be established.
(b) The following controls shall apply to security areas:
(1) Security areas shall be separated from adjacent areas by a physical barrier designed to prevent entrance into such areas, and access to the Restricted Data within the areas, by unauthorized individuals.
(2) During working hours, admittance shall be controlled by an appropriately cleared individual posted at each unlocked entrance.
(3) During nonworking hours, admittance shall be controlled by protective personnel on patrol, with protective personnel posted at unlocked entrances, or by such intrusion detection system as DOE approves.
(4) Each individual authorized to enter a security area shall be issued a distinctive badge or pass when the number of employees assigned to the area exceeds thirty.
Whenever armed protective personnel are required in accordance with § 1016.15, such protective personnel shall:
(a) Possess a “Q” or “L” access authorization or “Q(X)” or “L(X)” access authorization if the Restricted Data being protected is classified Confidential, or a “Q” access authorization or “Q(X)” access authorization if the Restricted Data being protected is classified Secret.
(b) Be armed with sidearms of 9mm or greater.
(a) Except as DOE may authorize, no person subject to the regulations in this part shall permit any individual to have access to Restricted Data in his possession unless the individual has an appropriate access authorization granted by DOE, or has been certified by DOD or NASA through DOE, and;
(1) The individual is authorized by an Access Permit to receive Restricted Data in the categories involved and the permittee determines that such access is required in the course of his duties, or
(2) The individual needs such access in connection with such duties as a DOE employee or DOE contractor employee, or as certified by DOD or NASA.
(b) Inquiries concerning the access authorization status of individuals, the scope of Access Permits, or the nature of contracts should be addressed to the cognizant DOE or NNSA office.
(a)
(b)
(c)
(a)
(2) In addition, such classified matter containing Restricted Data shall be transmitted only to persons who possess approved facilities for their physical security consistent with this part. Any person subject to the regulations in this part who transmits such Restricted Data containing Restricted Data shall be deemed to have fulfilled his obligations under this subparagraph by securing a written certification from the prospective recipient that such recipient possesses facilities for its physical security consistent with this part.
(3) Restricted Data shall not be exported from the United States without prior authorization from DOE.
(b)
(1) They shall be enclosed in two sealed, opaque envelopes or wrappers.
(2) The inner envelope or wrapper shall be addressed in the ordinary manner and sealed with tape, the appropriate classification shall be marked on both sides of the envelope, and any additional marking required by 10 CFR part 1045 shall be applied.
(3) The outer envelope or wrapper shall be addressed in the ordinary manner. No classification, additional marking, or other notation shall be affixed which indicates that the document enclosed therein contains classified information or Restricted Data.
(4) A receipt which identifies the document, the date of transfer, the recipient, and the person transferring the document shall accompany the document and shall be signed by the recipient and returned to the sender whenever the custody of a document containing Secret Restricted Data is transferred.
(c)
(1) The classified matter shall be so packaged that the classified characteristics will not be revealed.
(2) A receipt which identifies the classified matter, the date of shipment, the recipient, and the person transferring the classified matter shall accompany the classified matter, and the recipient shall sign such receipt whenever the custody of classified matter containing Secret Restricted Data is transferred.
(d)
(i) By messenger-courier system specifically created for that purpose and approved for use by DOE.
(ii) Registered mail.
(iii) By protective services provided by United States air or surface commercial carriers under such conditions as may be preserved by the DOE.
(iv) Individuals possessing appropriate DOE access authorization who have been given written authority by their employers.
(2) Confidential classified matter may be transported by one of the methods set forth in paragraph (d)(1) of this section or by U.S. first class, express, or certified mail.
(e)
Each permittee possessing classified matter (including classified matter in electronic format) containing Secret Restricted Data shall establish accountability procedures and shall maintain logs to document access to and record comprehensive disposition information for all such classified matter that has been in his custody at any time.
Classified matter containing Restricted Data shall not be downgraded or declassified except as authorized by DOE and in accordance with 10 CFR part 1045.
Documents containing Restricted Data may be destroyed by burning, pulping, or another method that assures complete destruction of the information which they contain. Restricted Data contained in classified matter, other than documents, may be destroyed only by a method that assures complete obliteration, removal, or destruction of the Restricted Data.
Storage, use, processing, and transmission of Restricted Data on computers, computer networks, electronic devices/media and mobile devices must be approved by DOE. DOE-approved methods must be used when destroying classified information that is in electronic format.
(a) In accordance with § 1016.12, if the need to use, process, store, reproduce, transmit, or handle classified matter no longer exists, the security facility approval will be terminated. The permittee may deliver all Restricted Data to the DOE or to a person authorized to receive them; or the permittee may destroy all such Restricted Data. In either case, the facility must submit a certification of non-possession of Restricted Data to the DOE.
(b) In any instance where security facility approval has been suspended or revoked based on a determination of the DOE that further possession of classified matter by the permittee would endanger the common defense and national security, the permittee shall, upon notice from the DOE, immediately deliver all Restricted Data to the DOE along with a certificate of non-possession of Restricted Data.
The DOE shall make such inspections and surveys of the premises, activities, records, and procedures of any person subject to the regulations in this part as DOE deems necessary to effectuate the purposes of the Act, Executive Order 13526, and DOE orders and procedures.
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
This action proposes to establish Class E airspace at Wessington Springs, SD. Controlled airspace is necessary to accommodate new Standard Instrument Approach
Comments must be received on or before January 3, 2017.
Send comments on this proposal to the U.S. Department of Transportation, Docket Operations, 1200 New Jersey Avenue SE., West Building Ground Floor, Room W12-140, Washington, DC 20590; telephone (202) 366-9826 or (800) 617-5527. You must identify the docket number FAA Docket No. FAA-2016-9193/Airspace Docket No.16-AGL-26, at the beginning of your comments. You may also submit comments through the Internet at
FAA Order 7400.11A, Airspace Designations and Reporting Points, and subsequent amendments can be viewed online at
FAA Order 7400.11, Airspace Designations and Reporting Points, is published yearly and effective on September 15.
Rebecca Shelby, Central Service Center, Operations Support Group, Federal Aviation Administration, Southwest Region, 10101 Hillwood Parkway, Fort Worth, TX 76177; telephone: 817-222-5857.
The FAA's authority to issue rules regarding aviation safety is found in Title 49 of the United States Code. Subtitle I, Section 106 describes the authority of the FAA Administrator. Subtitle VII, Aviation Programs, describes in more detail the scope of the agency's authority. This rulemaking is promulgated under the authority described in Subtitle VII, Part A, Subpart I, Section 40103. Under that section, the FAA is charged with prescribing regulations to assign the use of airspace necessary to ensure the safety of aircraft and the efficient use of airspace. This regulation is within the scope of that authority as it would establish Class E airspace at Wessington Springs Airport, Wessington Springs, SD.
Interested parties are invited to participate in this proposed rulemaking by submitting such written data, views, or arguments, as they may desire. Comments that provide the factual basis supporting the views and suggestions presented are particularly helpful in developing reasoned regulatory decisions on the proposal. Comments are specifically invited on the overall regulatory, aeronautical, economic, environmental, and energy-related aspects of the proposal. Communications should identify both docket numbers and be submitted in triplicate to the address listed above. Commenters wishing the FAA to acknowledge receipt of their comments on this notice must submit with those comments a self-addressed, stamped postcard on which the following statement is made: “Comments to Docket No. FAA-2016-9193/Airspace Docket No. 16-AGL-26.” The postcard will be date/time stamped and returned to the commenter.
All communications received before the specified closing date for comments will be considered before taking action on the proposed rule. The proposal contained in this notice may be changed in light of the comments received. A report summarizing each substantive public contact with FAA personnel concerned with this rulemaking will be filed in the docket.
An electronic copy of this document may be downloaded through the Internet at
You may review the public docket containing the proposal, any comments received and any final disposition in person in the Dockets Office (see
This document proposes to amend FAA Order 7400.11A, Airspace Designations and Reporting Points, dated August 3, 2016, and effective September 15, 2016. FAA Order 7400.11A is publicly available as listed in the
The FAA is proposing an amendment to Title 14, Code of Federal Regulations (14 CFR) Part 71 by establishing Class E airspace extending upward from 700 feet above the surface within a 6.5-mile radius of Wessington Springs Airport, Wessington Springs, SD, to accommodate new standard instrument approach procedures. Controlled airspace is needed for the safety and management of IFR operations at the airport.
Class E airspace areas are published in Paragraph 6005 of FAA Order 7400.11A, dated August 3, 2016, and effective September 15, 2016, which is incorporated by reference in 14 CFR 71.1. The Class E airspace designation listed in this document will be published subsequently in the Order.
The FAA has determined that this proposed regulation only involves an established body of technical regulations for which frequent and routine amendments are necessary to keep them operationally current, It, therefore: (1) Is not a “significant regulatory action” under Executive Order 12866; (2) is not a “significant rule” under DOT Regulatory Policies and Procedures (44 FR 11034; February 26, 1979); and (3) does not warrant preparation of a regulatory evaluation as the anticipated impact is so minimal. Since this is a routine matter that will only affect air traffic procedures and air navigation, it is certified that this rule, when promulgated, would not have a significant economic impact on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
This proposal will be subject to an environmental analysis in accordance with FAA Order 1050.1F, “Environmental Impacts: Policies and
Airspace, Incorporation by reference, Navigation (Air)
In consideration of the foregoing, the Federal Aviation Administration proposes to amend 14 CFR part 71 as follows:
49 U.S.C. 106(f), 106(g); 40103, 40113, 40120; E.O. 10854, 24 FR 9565, 3 CFR, 1959-1963 Comp., p. 389.
That airspace extending upward from 700 feet above the surface within a 6.5-mile radius of Wessington Springs Airport.
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
This action proposes to establish Class E en route airspace extending upward from 1,200 feet above the surface to accommodate Instrument Flight Rules (IFR) aircraft under control of the Denver Air Route Traffic Control Center (ARTCC), Denver, CO. Establishment of this airspace area would ensure controlled airspace exists in those areas where the Federal airway structure is inadequate.
Comments must be received on or before January 3, 2017.
Send comments on this proposal to the U.S. Department of Transportation, Docket Operations, 1200 New Jersey Avenue SE., West Building Ground Floor, Room W12-140, Washington, DC 20590; telephone: 1-800-647-5527, or (202) 366-9826. You must identify FAA Docket No. FAA-2016-9286; Airspace Docket No. 16-ANM-13, at the beginning of your comments. You may also submit comments through the Internet at
FAA Order 7400.11A, Airspace Designations and Reporting Points, and subsequent amendments can be viewed online at
FAA Order 7400.11, Airspace Designations and Reporting Points, is published yearly and effective on September 15.
Tom Clark, Federal Aviation Administration, Operations Support Group, Western Service Center, 1601 Lind Avenue SW., Renton, WA 98057; telephone (425) 203-4511.
The FAA's authority to issue rules regarding aviation safety is found in Title 49 of the United States Code. Subtitle I, Section 106 describes the authority of the FAA Administrator. Subtitle VII, Aviation Programs, describes in more detail the scope of the agency's authority. This rulemaking is promulgated under the authority described in Subtitle VII, Part A, Subpart I, Section 40103. Under that section, the FAA is charged with prescribing regulations to assign the use of airspace necessary to ensure the safety of aircraft and the efficient use of airspace. This regulation is within the scope of that authority as it would establish Class E en route airspace at Denver Air Route Traffic Control Center, Denver, CO.
Interested parties are invited to participate in this proposed rulemaking by submitting such written data, views, or arguments, as they may desire. Comments that provide the factual basis supporting the views and suggestions presented are particularly helpful in developing reasoned regulatory decisions on the proposal. Comments are specifically invited on the overall regulatory, aeronautical, economic, environmental, and energy-related aspects of the proposal. Communications should identify both docket numbers and be submitted in triplicate to the address listed above. Persons wishing the FAA to acknowledge receipt of their comments on this notice must submit with those comments a self-addressed, stamped postcard on which the following statement is made: “Comments to Docket No. FAA-2016-9286/Airspace Docket No. 16-ANM-13.” The postcard will be date/time stamped and returned to the commenter.
All communications received before the specified closing date for comments will be considered before taking action on the proposed rule. The proposal contained in this notice may be changed in light of the comments received. A report summarizing each substantive public contact with FAA personnel concerned with this rulemaking will be filed in the docket.
An electronic copy of this document may be downloaded through the Internet at
You may review the public docket containing the proposal, any comments received, and any final disposition in person in the Dockets Office (see the
This document proposes to amend FAA Order 7400.11A, Airspace Designations and Reporting Points, dated August 3, 2016, and effective September 15, 2016. FAA Order 7400.11A is publicly available as listed in the
Current airspace design is primarily based on airport terminal areas and airways, often leaving small areas of uncontrolled airspace between airports. Class E en route domestic airspace provides controlled airspace in those areas where there is a requirement to provide IFR en route air traffic control services but the Federal airway structure is inadequate.
Numerous smaller Class E en route areas have been established to provide controlled airspace where the airway structure is inadequate; however, additional areas of uncontrolled airspace have been discovered due to technological improvements in locating and mapping. Also, as aging ground-based navigation aids are removed from service, the airway structure is reduced, uncovering larger areas of uncontrolled airspace.
The FAA is proposing an amendment to Title 14 Code of Federal Regulations (14 CFR) Part 71 to establish Class E en route airspace extending upward from 1,200 feet above the surface at the Denver ARTCC, Denver, CO, to support en route IFR operations where the airway structure is inadequate. This proposal would allow the most efficient routing between airports without reducing margins of safety or requiring additional coordination and pilot/controller workload. This action is necessary to ensure the safety and management of controlled airspace within the National Airspace System as it transitions from ground based navigation aids to satellite-based Global Navigation Satellite System for navigation.
Class E airspace designations are published in paragraph 6006 of FAA Order 7400.11A, dated August 3, 2016, and effective September 15, 2016, which is incorporated by reference in 14 CFR 71.1. The Class E airspace designations listed in this document will be published subsequently in the Order.
The FAA has determined that this regulation only involves an established body of technical regulations for which frequent and routine amendments are necessary to keep them operationally current, is non-controversial and unlikely to result in adverse or negative comments. It, therefore: (1) Is not a “significant regulatory action” under Executive Order 12866; (2) is not a “significant rule” under DOT Regulatory Policies and Procedures (44 FR 11034; February 26, 1979); and (3) does not warrant preparation of a regulatory evaluation as the anticipated impact is so minimal. Since this is a routine matter that will only affect air traffic procedures and air navigation, it is certified that this rule, when promulgated, would not have a significant economic impact on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
This proposal will be subject to an environmental analysis in accordance with FAA Order 1050.1F, “Environmental Impacts: Policies and Procedures” prior to any FAA final regulatory action.
Airspace, Incorporation by reference, Navigation (air).
Accordingly, pursuant to the authority delegated to me, the Federal Aviation Administration proposes to amend 14 CFR part 71 as follows:
49 U.S.C. 106(f), 106(g), 40103, 40113, 40120; E.O. 10854, 24 FR 9565, 3 CFR, 1959-1963 Comp., p. 389.
2. The incorporation by reference in 14 CFR 71.1 of FAA Order 7400.11A, Airspace Designations and Reporting Points, dated August 3, 2016, and effective September 15, 2016, is amended as follows:
That airspace extending upward from 1,200 feet above the surface within an area bounded by lat. 44°57′30″ N., long. 103°10′00″ W.; to lat. 44°42′00″ N., long 101°29′00″ W.; to lat. 43°42′30″ N., long. 101°24′30″ W.; to lat. 43°17′20″ N., long. 100°06′00″ W.; to lat. 42°00′00″ N., long. 099°01′00″ W.; to lat. 39°59′00″ N., long. 099°03′30″ W.; to lat. 39°28′00″ N., long. 098°48′00″ W.; to lat. 37°30′00″ N., long. 102°33′00″ W.; to lat. 36°43′00″ N., long. 105°00′00″ W.; to lat. 36°43′00″ N., long. 106°05′00″ W.; to lat. 36°12′00″ N., long. 107°28′00″ W.; to lat. 36°02′00″ N., long. 108°13′00″ W.; to lat. 35°42′00″ N., long. 110°14′00″ W.; to lat. 35°46′00″ N., long. 111°50′30″ W.; to lat. 36°25′15″ N., long. 111°30′15″ W.; to lat. 36°44′00″ N., long. 111°36′30″ W.; to lat. 37°24′45″ N., long. 111°52′45″ W.; to lat. 37°50′00″ N., long. 110°53′00″ W.; to lat. 38°07′45″ N., long. 110°09′25″ W.; to lat. 38°12′00″ N., long. 109°59′00″ W.; to lat. 38°56′00″ N., long. 109°59′00″ W.; to lat. 39°13′00″ N., long. 109°59′00″ W.; to lat. 39°35′00″ N., long. 110°18′00″ W.; to lat. 40°00′00″ N., long. 109°10′00″ W.; to lat. 40°51′00″ N., long. 109°06′00″ W.; to lat. 41°22′00″ N., long. 108°16′30″ W.; to lat. 41°36′30″ N., long. 108°00′00″ W.; to lat. 42°25′00″ N., long. 107°03′00″ W.; to lat. 43°53′00″ N., long. 107°17′00″ W.; to lat. 44°19′00″ N., long. 106°16′00″ W.; to lat. 45°14′15″ N., long. 106°00′00″ W.; to lat. 45°07′00″ N., long. 104°15′00″ W.; thence to the point of beginning.
Coast Guard, DHS.
Notice of proposed rulemaking.
The Coast Guard proposes to establish a safety zone in the West Duwamish Waterway in Seattle, Washington for scheduled drydock movements at Vigor Industrial. The safety zone is necessary to ensure the
Comments and related material must be received by the Coast Guard on or before January 17, 2017.
You may submit comments identified by docket number USCG-2015-1061 using the Federal eRulemaking Portal at
If you have questions about this proposed rulemaking, call or email Lieutenant Commander Christina Sullivan, Waterways Management Division, Sector Puget Sound, U.S. Coast Guard; telephone (206) 217-6051, email
The Coast Guard periodically receives notification from Vigor Industrial regarding their scheduled drydock movements in the West Duwamish Waterway, and has established temporary safety zones to ensure the safety of the maritime public during Vigor Industrial's operations. The Coast Guard published a temporary safety zone; Vigor Industrial Ferry Construction, West Duwamish Waterway, Seattle, WA on September 9, 2014 (79 FR 53297).
Due to the dangers involved with a large, slow moving drydock that will be maneuvering close to the shore, the Coast Guard proposes the establishment of a short term safety zone that is activated on a notice of enforcement to ensure the safety of the workers involved as well as the maritime public during Vigor Industrial's operations.
The Coast Guard proposes this rulemaking under authority in 33 U.S.C. 1231. Coast Guard Captains of the Port are granted authority to establish safety and security zones in 33 CFR 1.05-1(f) for safety and environmental purposes as described in 33 CFR part 165.
Vigor Industrial periodically conducts drydock movements in support of its vessel launching operations in the West Duwamish Waterway in Seattle, Washington. The Coast Guard proposes to establish a safety zone to ensure the safety of the workers involved as well as the maritime public during Vigor Industrial's operations, and would do so by prohibiting any person or vessel from entering or remaining in the safety zone unless authorized by the Captain of the Port (COTP) or a Designated Representative.
The Coast Guard is establishing a safety zone encompassing all waters in a rectangle approximately 450-yards-by-500-yards at the mouth of the West Duwamish Waterway as it empties into Elliot Bay in Seattle, Washington. The safety zone is adjacent to the northeastern tip of Harbor Island in Seattle, WA.
To request permission to enter the zone during the times set out by the notice of enforcement contact the Joint Harbor Operations Center at 206-217-6001 or the Vessel Traffic Service Puget Sound on VHF Channel 14. If permission for entry is granted vessels would be required proceed at a minimum speed for navigation.
We developed this proposed rule after considering numerous statutes and executive orders (E.O.s) related to rulemaking. Below we summarize our analyses based on a number of these statutes and E.O.s, and we discuss First Amendment rights of protestors.
E.O.s 12866 and 13563 direct agencies to assess the costs and benefits of available regulatory alternatives and, if regulation is necessary, to select regulatory approaches that maximize net benefits. E.O. 13563 emphasizes the importance of quantifying both costs and benefits, of reducing costs, of harmonizing rules, and of promoting flexibility. This NPRM has not been designated a “significant regulatory action,” under E.O. 12866. Accordingly, the NPRM has not been reviewed by the Office of Management and Budget.
This regulatory action determination is based on the size, location, and duration of the safety zone. This safety zone would impact a small designated area of the West Duwamish Waterway for less than 6 hours per occurrence. From 2005 through 2015, there were a total of 10 instances in which the Coast Guard issued a safety zone for the movement of the Vigor Dry Dock. Moreover, the Coast Guard would issue a Broadcast Notice to Mariners via VHF-FM marine channel 16 about the zone, and the rule would allow vessels to seek permission to enter the zone.
The Regulatory Flexibility Act of 1980, 5 U.S.C. 601-612, as amended, requires Federal agencies to consider the potential impact of regulations on small entities during rulemaking. The term “small entities” comprises small businesses, not-for-profit organizations that are independently owned and operated and are not dominant in their fields, and governmental jurisdictions with populations of less than 50,000. The Coast Guard certifies under 5 U.S.C. 605(b) that this proposed rule would not have a significant economic impact on a substantial number of small entities.
While some owners or operators of vessels intending to transit the safety zone may be small entities, for the reasons stated in section IV.A above this proposed rule would not have a significant economic impact on any vessel owner or operator.
If you think that your business, organization, or governmental jurisdiction qualifies as a small entity and that this rule would have a significant economic impact on it, please submit a comment (see
Under section 213(a) of the Small Business Regulatory Enforcement Fairness Act of 1996 (Pub. L. 104-121), we want to assist small entities in understanding this proposed rule. If the rule would affect your small business, organization, or governmental jurisdiction and you have questions concerning its provisions or options for compliance, please contact the person listed in the
This proposed rule would not call for a new collection of information under the Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3520).
A rule has implications for federalism under E.O. 13132, Federalism, if it has
This proposed rule was determined to have potential tribal implications under Executive Order 13175, Consultation and Coordination with Indian Tribal Governments, because it would impact vessel traffic in the West Duwamish Waterway. The Coast Guard consulted with the Muckleshoot tribe on this notice of proposed rulemaking. In order to reach an agreeable timeframe that avoids impacts to treaty fishing activities, the Coast Guard will consult with the Muckleshoot tribe and Vigor Industrial once it receives notification from Vigor Industrial concerning drydock movements that require the enforcement of the safety zone. If agreement is not reached, the Coast Guard, as a Federal trustee, will conduct consultation with the Muckleshoot tribe to ensure Vigor movements will avoid Treaty impacts.
If you believe this proposed rule has additional implications for federalism or Indian tribes, please contact the person listed in the
The Unfunded Mandates Reform Act of 1995 (2 U.S.C. 1531-1538) requires Federal agencies to assess the effects of their discretionary regulatory actions. In particular, the Act addresses actions that may result in the expenditure by a State, local, or tribal government, in the aggregate, or by the private sector of $100,000,000 (adjusted for inflation) or more in any one year. Though this proposed rule would not result in such an expenditure, we do discuss the effects of this rule elsewhere in this preamble.
We have analyzed this proposed rule under Department of Homeland Security Management Directive 023-01 and Commandant Instruction M16475.lD, which guide the Coast Guard in complying with the National Environmental Policy Act of 1969 (NEPA)(42 U.S.C. 4321-4370f), and have made a preliminary determination that this action is one of a category of actions that do not individually or cumulatively have a significant effect on the human environment. This proposed rule involves the establishment of a safety zone to ensure the safety of the maritime public. Normally such actions are categorically excluded from further review under paragraph 34(g) of Figure 2-1 of the Commandant Instruction. A preliminary environmental analysis checklist supporting this determination and a Categorical Exclusion Determination are available in the docket where indicated under
The Coast Guard respects the First Amendment rights of protesters. Protesters are asked to contact the person listed in the
We view public participation as essential to effective rulemaking, and will consider all comments and material received during the comment period. Your comment can help shape the outcome of this rulemaking. If you submit a comment, please include the docket number for this rulemaking, indicate the specific section of this document to which each comment applies, and provide a reason for each suggestion or recommendation.
We encourage you to submit comments through the Federal eRulemaking Portal at
We accept anonymous comments. All comments received will be posted without change to
Documents mentioned in this NPRM as being available in the docket, and all public comments, will be in our online docket at
Harbors, Marine safety, Navigation (water), Reporting and record keeping requirements, Security measures, Waterways.
For the reasons discussed in the preamble, the Coast Guard proposes to amend 33 CFR part 165 as follows:
33 U.S.C. 1226, 1231; 46 U.S.C. Chapter 701, 3306, 3703; 50 U.S.C. 191, 195; 33 CFR 1.05-1, 6.04-1, 6.04-6, 160.5; Pub. L. 107-295, 116 Stat. 2064; Department of Homeland Security Delegation No. 0170.1.
(a)
(b)
(2) In order to reach an agreeable timeframe that avoids impacts to treaty fishing activities, the Coast Guard will consult with the Muckleshoot tribe and Vigor Industrial once it receives notification from Vigor Industrial concerning drydock movements that require the enforcement of the safety zone. If agreement is not reached, the Coast Guard, as a Federal trustee, will conduct consultation with the Muckleshoot tribe to ensure Vigor movements will avoid Treaty impacts.
(c)
Environmental Protection Agency (EPA).
Proposed rule.
EPA is proposing to add a nonylphenol ethoxylates (NPEs) category to the list of toxic chemicals subject to reporting under section 313 of the Emergency Planning and Community Right-to-Know Act (EPCRA) and section 6607 of the Pollution Prevention Act (PPA). EPA is proposing to add this chemical category to the EPCRA section 313 list because EPA believes NPEs meet the EPCRA section 313(d)(2)(C) toxicity criteria. Specifically, EPA believes that longer chain NPEs can break down in the environment to short-chain NPEs and nonylphenol, both of which are highly toxic to aquatic organisms. Based on a review of the available production and use information, members of the NPEs category are expected to be manufactured, processed, or otherwise used in quantities that would exceed EPCRA section 313 reporting thresholds.
Comments must be received on or before January 17, 2017.
Submit your comments, identified by Docket ID No. EPA-HQ-TRI-2016-0222, by one of the following methods:
•
•
•
Additional instructions on commenting or visiting the docket, along with more information about dockets generally, is available at
You may be potentially affected by this action if you manufacture, process, or otherwise use NPEs. The following list of North American Industrial Classification System (NAICS) codes is not intended to be exhaustive, but rather provides a guide to help readers determine whether this document applies to them. Potentially affected entities may include:
• Facilities included in the following NAICS manufacturing codes (corresponding to Standard Industrial Classification (SIC) codes 20 through 39): 311 *, 312 *, 313 *, 314 *, 315 *, 316, 321, 322, 323 *, 324, 325 *, 326 *, 327, 331, 332, 333, 334 *, 335 *, 336, 337 *, 339 *, 111998 *, 211112 *, 212324 *, 212325 *, 212393 *, 212399 *, 488390 *, 511110, 511120, 511130, 511140 *, 511191, 511199, 512220, 512230 *, 519130 *, 541712 *, or 811490 *.
* Exceptions and/or limitations exist for these NAICS codes.
• Facilities included in the following NAICS codes (corresponding to SIC codes other than SIC codes 20 through 39): 212111, 212112, 212113 (corresponds to SIC code 12, Coal Mining (except 1241)); or 212221, 212222, 212231, 212234, 212299 (corresponds to SIC code 10, Metal Mining (except 1011, 1081, and 1094)); or 221111, 221112, 221113, 221118, 221121, 221122, 221330 (Limited to facilities that combust coal and/or oil for the purpose of generating power for distribution in commerce) (corresponds to SIC codes 4911, 4931, and 4939, Electric Utilities); or 424690, 425110, 425120 (Limited to facilities previously classified in SIC code 5169, Chemicals and Allied Products, Not Elsewhere Classified); or 424710 (corresponds to SIC code 5171, Petroleum Bulk Terminals and Plants); or 562112 (Limited to facilities primarily engaged in solvent recovery services on a contract or fee basis (previously classified under SIC code 7389, Business Services, NEC)); or 562211, 562212, 562213, 562219, 562920 (Limited to facilities regulated under the Resource Conservation and Recovery Act, subtitle C, 42 U.S.C. 6921
• Federal facilities.
To determine whether your facility would be affected by this action, you should carefully examine the applicability criteria in part 372, subpart B of Title 40 of the Code of Federal Regulations. If you have questions regarding the applicability of this action to a particular entity, consult the person listed under
EPA is proposing to add a NPEs category to the list of toxic chemicals subject to reporting under EPCRA section 313 and PPA section 6607. As discussed in more detail later in this document, EPA is proposing to add this chemical category to the EPCRA section 313 list because EPA believes NPEs meet the EPCRA section 313(d)(2)(C) toxicity criteria.
This action is issued under EPCRA sections 313(d) and 328, 42 U.S.C. 11023
Section 313 of EPCRA, 42 U.S.C. 11023, requires certain facilities that manufacture, process, or otherwise use listed toxic chemicals in amounts above reporting threshold levels to report their environmental releases and other waste management quantities of such chemicals annually. These facilities must also report pollution prevention and recycling data for such chemicals, pursuant to section 6607 of the PPA, 42 U.S.C. 13106. Congress established an initial list of toxic chemicals that was comprised of 308 individually listed chemicals and 20 chemical categories.
EPCRA section 313(d) authorizes EPA to add or delete chemicals from the list and sets criteria for these actions. EPCRA section 313(d)(2) states that EPA may add a chemical to the list if any of the listing criteria in EPCRA section 313(d)(2) are met. Therefore, to add a chemical, EPA must demonstrate that at least one criterion is met, but need not determine whether any other criterion is met. Conversely, to remove a chemical from the list, EPCRA section 313(d)(3) dictates that EPA must demonstrate that none of the criteria in ECPRA section 313(d)(2) are met. The listing criteria in EPCRA section 313(d)(2)(A)-(C) are as follows:
• The chemical is known to cause or can reasonably be anticipated to cause significant adverse acute human health effects at concentration levels that are reasonably likely to exist beyond facility site boundaries as a result of continuous, or frequently recurring, releases.
• The chemical is known to cause or can reasonably be anticipated to cause in humans: Cancer or teratogenic effects, or serious or irreversible reproductive dysfunctions, neurological disorders, heritable genetic mutations, or other chronic health effects.
• The chemical is known to cause or can be reasonably anticipated to cause, because of its toxicity, its toxicity and persistence in the environment, or its toxicity and tendency to bioaccumulate in the environment, a significant adverse effect on the environment of sufficient seriousness, in the judgment of the Administrator, to warrant reporting under this section.
EPA often refers to the EPCRA section 313(d)(2)(A) criterion as the “acute human health effects criterion;” the EPCRA section 313(d)(2)(B) criterion as the “chronic human health effects criterion;” and the EPCRA section 313(d)(2)(C) criterion as the “environmental effects criterion.”
EPA published in the
NPEs are nonionic surfactants containing a branched nine-carbon alkyl chain bound to phenol and a chain of repeating ethoxylate units (C
EPA is proposing to list NPEs as a category that would include the thirteen NPEs that currently appear on the Toxic Substances Control Act inventory (
7311-27-5; Ethanol, 2-[2-[2-[2-(4-nonylphenoxy)ethoxy]ethoxy]ethoxy]-
9016-45-9; Poly(oxy-1,2-ethanediyl), α-(nonylphenyl)-ω-hydroxy-
20427-84-3; Ethanol, 2-[2-(4-nonylphenoxy)ethoxy]-
26027-38-3; Poly(oxy-1,2-ethanediyl), α-(4-nonylphenyl)-ω-hydroxy-
26571-11-9; 3,6,9,12,15,18,21,24-Octaoxahexacosan-1-ol, 26-(nonylphenoxy)-
27176-93-8; Ethanol, 2-[2-(nonylphenoxy)ethoxy]-
27177-05-5; 3,6,9,12,15,18,21-Heptaoxatricosan-1-ol, 23-(nonylphenoxy)-
27177-08-8; 3,6,9,12,15,18,21,24,27-Nonaoxanonacosan-1-ol, 29-(nonylphenoxy)-
27986-36-3; Ethanol, 2-(nonylphenoxy)-
37205-87-1; Poly(oxy-1,2-ethanediyl), α-(isononylphenyl)-ω-hydroxy-
51938-25-1; Poly(oxy-1,2-ethanediyl), α-(2-nonylphenyl)-ω-hydroxy-
68412-54-4; Poly(oxy-1,2-ethanediyl), α-(nonylphenyl)-ω-hydroxy-, branched
127087-87-0; Poly(oxy-1,2-ethanediyl), α-(4-nonylphenyl)-ω-hydroxy-, branched
EPA prepared two technical documents to support the listing of the NPEs category. The first document is “Chemistry and Environmental Fate of ol Ethoxylates (NPEs)” (Ref. 7), which provides detailed information on the chemistry and environmental fate of NPEs. The second document is “Ecological Hazard Assessment for Nonylphenol Monoethoxylate (NP1EO) and Nonylphenol Diethoxylate (NP2EO)” (Ref. 8), which provides an assessment of the ecological toxicity of short-chain NPEs. Unit III.A. provides a brief summary of the chemistry and environmental fate of NPEs and Unit III.B. provides a brief summary of the ecological toxicity of short-chain NPEs. Readers should consult the support documents (Refs. 7 and 8) for further information.
In the environment, NPEs (in particular, those containing long ethoxylate chains) are expected to have very low volatility based on Henry's law constant values of <9.8 × 10
Biodegradation is the dominant fate process for NPEs in the environment; abiotic degradation processes such as hydrolysis are not expected to be significant (Ref. 9). The available data indicate that NPEs undergo rapid primary biodegradation but slow ultimate biodegradation (Refs. 11, 12, 13, 14, 15, 16, 17, 18, and 19). Half-lives ranging from 2 to 57.8 days have been determined for these substances based on river water die-away studies, which report primary degradation (Ref. 13). Anaerobic biodegradation appears to proceed more slowly than aerobic biodegradation (Ref. 13). Nonylphenol ethoxylate biodegradation products include shorter chain NPEs and ethoxycarboxylates. (Refs. 9, 10, and 20). Nonylphenol ethoxycarboxylates are NPEs that terminate with a carboxylate group (-CO
Well-designed and properly functioning wastewater treatment plants (WWTPs) can greatly reduce effluent concentrations of NPEs and their degradation products relative to those found in the influent (Ref. 28). However, treatment efficiency varies considerably for WWTPs depending on plant design and operating conditions (Refs. 10, 29, 30, 31, and 32). WWTP effluent remains a significant source of NPEs, nonylphenol ethoxycarboxylates, and nonylphenol in the environment, and concentrations of these compounds in surface waters, sediments, and wildlife tend to be higher near WWTP outfalls (Refs. 10, 31, 33, 34, 35, 36, and 37).
Nonylphenol ethoxylates and the degradation products, nonylphenol ethoxycarboxylates and nonylphenol, are widely distributed in surface waters, including rivers, lakes, estuaries, marine ecosystems, and their underlying sediments (Refs. 10, 31, 33, 34, 35, 38, 39, 40, and 41). The more hydrophobic of these compounds, such as nonylphenol, NP1EO, and NP2EO, tend to partition to sediments (Ref. 10). Because sediments are often anaerobic, sorbed nonylphenol ethoxylates and their degradation products undergo further biodegradation slowly, ultimately producing nonylphenol. Through a combination of strong sorption and slow biodegradation, NPEs and nonylphenol can accumulate in sediments in concentrations that are much higher than are found in the surrounding water (Refs. 10 and 37) and can persist for years (Ref. 42).
For NPEs, aquatic toxicity generally decreases as the length of the ethoxylate chain increases (Refs. 43 and 44). The available data show that NP1EO and NP2EO are significantly more toxic to aquatic organisms than the longer chain ethoxylates (
The available experimental data demonstrate that NP1EO and NP2EO have been shown to cause acute and chronic toxicity to aquatic organisms at very low concentrations (Ref. 8). They have been shown to reduce individual survival, growth, and reproduction in aquatic organisms and NP2EO has been shown to reduce testicular growth and GSI in fish. The concentrations at which toxicity is observed are well below 1 mg/L and as low as 148 μg/L for acute effects and less than 0.1 mg/L for chronic effects. Acute and chronic toxicity values at these low concentrations show that NP1EO and NP2EO are highly toxic to aquatic organisms.
The NPEs category that EPA is proposing to add to the EPCRA section 313 toxic chemical list, contains both short and long-chain NPEs. Short-chain NPEs are highly toxic to aquatic organisms with toxicity values well below 1 mg/L as described in Unit III. Therefore, EPA believes that the evidence is sufficient for listing short-chain NPEs on the EPCRA section 313 toxic chemical list pursuant to EPCRA section 313(d)(2)(C) based on the available ecological toxicity data. Long-chain NPEs, while not as toxic as short-chain NPEs, degrade in the environment to produce products that include highly toxic short-chain NPEs and nonylphenol. Nonylphenol is even more toxic to aquatic organisms than short-chain NPEs and was added to the EPCRA section 313 toxic chemical list based on its toxicity to aquatic organisms (79 FR 58686, FRL-9915-59-OEI, September 30, 2014). As a source of degradation products that are highly toxic to aquatic organisms, EPA believes that the evidence is sufficient for listing long-chain NPEs on the EPCRA section 313 toxic chemical list pursuant to EPCRA section 313(d)(2)(C) based on the available ecological toxicity and environmental fate data.
EPA does not believe that it is appropriate to consider exposure for chemicals that are highly toxic based on a hazard assessment when determining if a chemical can be added for environmental effects pursuant to EPCRA section 313(d)(2)(C) (see 59 FR 61440-61442). Therefore, in accordance with EPA's standard policy on the use of exposure assessments (see November 30, 1994 (59 FR 61432) (FRL-4922-2)), EPA does not believe that an exposure assessment is necessary or appropriate for determining whether NPEs meet the criteria of EPCRA section 313(d)(2)(C).
The following is a listing of the documents that are specifically referenced in this document. The docket includes these documents and other information considered by EPA, including documents that are referenced within the documents that are included in the docket, even if the referenced document is not itself physically located in the docket. For assistance in locating these other documents, please consult the person listed under
Additional information about these statutes and Executive Orders can be found at
This action is not a significant regulatory action and was therefore not submitted to the Office of Management and Budget (OMB) for review under Executive Orders 12866 (58 FR 51735, October 4, 1993) and 13563 (76 FR 3821, January 21, 2011).
This action does not contain any new information collection requirements that require additional approval by OMB under the PRA, 44 U.S.C. 3501
OMB has approved the reporting and recordkeeping requirements related to Forms A and R, supplier notification, and petitions under OMB Control number 2025-0009 (EPA Information Collection Request (ICR) No. 1363) and those related to trade secret designations under OMB Control 2050-0078 (EPA ICR No. 1428). As provided in 5 CFR 1320.5(b) and 1320.6(a), an Agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. The OMB control numbers relevant to EPA's regulations are listed in 40 CFR part 9 or 48 CFR chapter 15, and displayed on the information collection instruments (
I certify that this action will not have a significant economic impact on a substantial number of small entities under the RFA, 5 U.S.C. 601
This action does not contain an unfunded mandate of $100 million or more as described in UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect small governments. This action is not subject to the requirements of UMRA because it contains no regulatory requirements that might significantly or uniquely affect small governments. EPA did not identify any small governments that would be impacted by this action. EPA's economic analysis indicates that the total cost of this action is estimated to be $619,627 in the first year of reporting (Ref. 50).
This action does not have federalism implications as specified in Executive Order 13132 (64 FR 43255, August 10, 1999). It will not have substantial direct effects on the States, on the relationship between the national government and the States, or on the distribution of power and responsibilities among the various levels of government.
This action does not have tribal implications as specified in Executive Order 13175 (65 FR 67249, November 9, 2000). This action relates to toxic chemical reporting under EPCRA section 313, which primarily affects private sector facilities. Thus, Executive Order 13175 does not apply to this action.
EPA interprets Executive Order 13045 (62 FR 19885, April 23, 1997) as applying only to those regulatory actions that concern environmental health or safety risks that EPA has reason to believe may disproportionately affect children, per the definition of “covered regulatory action” in section 2-202 of the Executive Order. This action is not subject to Executive Order 13045 because it does not concern an environmental health risk or safety risk.
This action is not subject to Executive Order 13211 (66 FR 28355, May 22, 2001), because it is not a significant regulatory action under Executive Order 12866.
This rulemaking does not involve technical standards and is therefore not subject to considerations under section 12(d) of NTTAA, 15 U.S.C. 272 note.
EPA has determined that this action will not have disproportionately high and adverse human health or environmental effects on minority or low-income populations as specified in Executive Order 12898 (59 FR 7629, February 16, 1994). This action does not address any human health or environmental risks and does not affect the level of protection provided to human health or the environment. This action adds an additional chemical to the EPCRA section 313 reporting requirements. By adding a chemical to the list of toxic chemicals subject to reporting under section 313 of EPCRA, EPA would be providing communities across the United States (including minority populations and low income populations) with access to data which they may use to seek lower exposures and consequently reductions in chemical risks for themselves and their children. This information can also be used by government agencies and others to identify potential problems, set priorities, and take appropriate steps to reduce any potential risks to human health and the environment. Therefore, the informational benefits of the action would have positive human health and environmental impacts on minority populations, low-income populations, and children.
Environmental protection, Community right-to-know, Reporting and recordkeeping requirements, and Toxic chemicals.
Therefore, it is proposed that 40 CFR chapter I be amended as follows:
42 U.S.C. 11023 and 11048.
(c) * * *
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Proposed rule; reopening of public comment period.
We, the National Marine Fisheries Service (NMFS), are reopening the public comment period on the proposed rule under the Marine Mammal Protection Act (MMPA) to prohibit swimming with and approaching a Hawaiian spinner dolphin within 50 yards (45.7 m) (for persons, vessels, and objects), including approach by interception. The comment period for the proposed rule that published on August 24, 2016 (81 FR 57854) closed on October 23, 2016. NMFS is reopening the public comment period for an additional 15 days to provide the public with additional time to submit information and to comment on this proposed rule.
Written comments on this proposed rule must be received by December 1, 2016. Comments received between the close of the first comment period on October 23, 2016, and the reopening of the comment period November 16, 2016 will be considered timely received.
You may submit comments, information, or data on the proposed rule, identified by NOAA-2005-0226, and on the Draft Environmental Impact Statement (DEIS) by either of the following methods:
The DEIS and references can be found online at
Hilo Library, 300 Waianuenue Ave., Hilo, HI 96720;
Kailua-Kona Library, 75-138 Hualalai Rd., Kailua Kona, HI 96740;
Kealakekua Library, 81-6619 Mamalahoa Hwy., Kealakekua, HI 96750;
Pahoa Library, 15-3070 Pahoa-Kalapana Rd., Pahoa, HI 96778;
Kihei Library, 35 Waimahaihai St., Kihei, HI 96753;
Lahaina Library, 680 Wharf St., Lahaina, HI 96761;
Lanai Library, 555 Fraser Ave., Lanai City, HI 96763;
Hawaii State Library, 478 S. King St., Honolulu, HI 96813;
Waianae Library, 85-625 Farrington Hwy., Waianae, HI 96792; and
Lihue Library, 4344 Hardy St., Lihue, HI 96766;
Susan Pultz, NMFS, Pacific Islands Region, Chief, Conservation Planning and Rulemaking Branch, 808-725-5150; or Trevor Spradlin, NMFS, Office of Protected Resources, Acting Chief, Marine Mammal and Sea Turtle Conservation Division, 301-427-8402.
On August 24, 2016, we published a proposed rule to prohibit swimming with and approaching a Hawaiian spinner dolphin within 50 yards (45.7 meters) (for persons, vessels, and objects), including approach by interception. These proposed regulatory measures are intended to prevent take, as defined under the Marine Mammal Protection Act (MMPA), of Hawaiian spinner dolphins from occurring in marine areas where viewing pressures are most prevalent. The proposed rule allowed for a 60-day public comment period, which ended on October 23, 2016.
NMFS has received several requests to extend the public comment period. These requests indicated that additional time was needed to consider more fully the proposed rulemaking and DEIS and to provide comments on the proposed regulations. Requests also indicated that additional time was needed for tour operators to compile and provide data with regard to spinner dolphin use of coastal habitats from multiple years of logbook records. In response to these requests, we are reopening the public comment period until December 1, 2016, to receive additional information and comments that may be relevant to any aspect of the proposal. Comments and information submitted during the prior comment period will be fully considered in the preparation of the final rule and need not be resubmitted.
16 U.S.C. 1361
Food Safety and Inspection Service, USDA.
Notice.
The Food Safety and Inspection Service (FSIS) is announcing that while FSIS is in the process of rulemaking to update the Nutrition Facts label format for meat and poultry products, establishments may voluntarily choose to use the Nutrition Facts label format that the Food and Drug Administration (FDA) recently finalized (“Food Labeling: Revision of the Nutrition and Supplement facts labels”, May 27, 2016; 81 FR 33742; and “Food Labeling: Serving Sizes of Foods That Can Reasonably be Consumed at One-Eating Occasion; Dual-Column Labeling; Updating, Modifying, and Establishing Certain Reference Amounts Customarily Consumed; Serving Size for Breath Mints; and Technical Amendments”; May 27, 2016; 81 FR 34000). As long as the information on the labels is still truthful and not misleading, FSIS will not find noncompliance if companies use the FDA format. When FSIS publishes a final rule to update the Nutrition Facts label format for meat and poultry products, companies would have to comply with that final rule by the effective date and will no longer be able to use the FDA format if it is different from the FSIS format.
Comments must be received by December 16, 2016.
FSIS invites interested persons to submit comments on this notice. Comments may be submitted by one of the following methods:
•
•
•
Jeff Canavan, Deputy Director, Labeling and Program Delivery Staff, Office of Policy and Program Development, Food Safety and Inspection Service, U.S. Department of Agriculture, Stop Code 3784, Patriots Plaza 3, 8-161A, 1400 Independence Avenue SW., Washington, DC 20250-3700; Telephone (301) 504-0879; Fax (202) 245-4792.
FSIS is the public health regulatory agency in the USDA that is responsible for ensuring that the nation's commercial supply of meat, poultry, and egg products is safe, wholesome, and accurately labeled and packaged. Under the Federal Meat Inspection Act (FMIA) (21 U.S.C. 601-695, at 607), the Poultry Products Inspection Act (PPIA) (21 U.S.C. 451-470, at 457), and the Egg Products Inspection Act (21 U.S.C. 1031-1056, at 1036) (the “Acts”), the labels of meat, poultry, and egg products must be approved by the Secretary of Agriculture, who has delegated this authority to FSIS, before these products can enter commerce. The Acts prohibit the sale or offer for sale by any person, firm, or corporation of any article in commerce under any name or other marking or labeling that is false or misleading or in any container of a misleading form or size (21 U.S.C. 607(d); 21 U.S.C. 457(c)). The Acts also prohibit the distribution in commerce of meat or poultry products that are adulterated or misbranded. The FMIA and PPIA give FSIS broad authority to promulgate such rules and regulations as are necessary to carry out the provisions of the Acts (21 U.S.C. 621 and 463(b)).
To prevent meat and poultry products from being misbranded, the meat and poultry product inspection regulations require that the labels of meat and poultry products include specific information, such as nutrition labels, and that such information be displayed as prescribed in the regulations (9 CFR part 317 and part 381). The nutrition labeling requirements for meat and meat food products are in 9 CFR 317.300-317.400, and the nutrition labeling requirements for poultry products are in 9 CFR 381.400-381.500.
On May 27, 2016, FDA published two final rules, “Food Labeling: Revision of the Nutrition and Supplement Facts Labels” (81 FR 33742) and “Food Labeling: Serving Sizes of Foods That Can Reasonably Be Consumed at One-Eating Occasion; Dual-Column Labeling; Updating, Modifying, and Establishing Certain Reference Amounts Customarily Consumed; Serving Size for Breath Mints; and Technical Amendments” (81 FR 34000), to update the Nutrition Facts label to reflect newer nutrition and public health research and recent dietary recommendations from expert groups and to improve the presentation of nutrition information to help consumers make more informed choices and maintain healthy dietary practices. FSIS has reviewed FDA's analysis and believes it is necessary to propose nutrition labeling regulations for meat and poultry products that will parallel, to the extent possible, FDA's regulations. This approach will help prevent consumer confusion and nonuniformity in the marketplace. While FSIS is in the process of rulemaking to update the Nutrition Facts label format for meat and poultry
No agency, officer, or employee of the USDA shall, on the grounds of race, color, national origin, religion, sex, gender identity, sexual orientation, disability, age, marital status, family/parental status, income derived from a public assistance program, or political beliefs, exclude from participation in, deny the benefits of, or subject to discrimination, any person in the United States under any program or activity conducted by the USDA.
To file a complaint of discrimination, complete the USDA Program Discrimination Complaint Form, which may be accessed online at:
Send your completed complaint form or letter to USDA by mail, fax, or email:
Persons with disabilities who require alternative means for communication (Braille, large print, audiotape, etc.) should contact USDA's TARGET Center at (202) 720-2600 (voice and TDD).
Public awareness of all segments of rulemaking and policy development is important. Consequently, in an effort to ensure that minorities, women, and persons with disabilities are aware of this notice, FSIS will announce it on-line through the FSIS Web page located at
FSIS also will make copies of this
Options range from recalls to export information to regulations, directives and notices. Customers can add or delete subscriptions themselves and have the option to password protect their account.
Bureau of the Census, Department of Commerce.
Notice of Advisory Committee charter renewal.
The Secretary of Commerce has determined that renewal of the charter of the Federal Economic Statistics Advisory Committee (FESAC) is necessary and in the public interest in connection with the performance of duties imposed by law on the U.S. Department of Commerce, and with the concurrence of the General Services Administration, established within the Economics and Statistics Administration (ESA), Department of Commerce. The renewed FESAC charter can be found on the Bureau of the Census' (Census Bureau's) Advisory Committee Web site at the following link:
James R. Spletzer, Designated Federal Official for the Federal Economic Statistics Advisory Committee, Principal Economist, U.S. Census Bureau, Room 5K019, Washington, DC 20233, telephone 301-763-4069,
The Committee presents advice and makes recommendations to the Department of Labor, Bureau of Labor Statistics and the Department of Commerce's bureaus consisting of ESA, the Bureau of Economic Analysis, and the Census Bureau (the Agencies) from the perspective of the professional economics and statistics community. The Committee examines the Agencies' programs and provides advice on statistical methodology, research needed, and other technical matters related to the collection, tabulation, and analysis of Federal economic statistics.
The Committee is a technical committee that is balanced in terms of the professional expertise required. It consists of approximately 16 members, appointed by the Agencies. Its members are economists, statisticians, and behavioral scientists who are recognized for their attainments and objectivity in their respective fields.
The FESAC will function solely as an advisory body and in compliance with provisions of the Federal Advisory Committee Act. Pursuant to subsection 9(c) of the Federal Advisory Committee Act, 5 U.S.C., App., as amended, this charter was filed with the Chief
• Senate Committee on Appropriations;
• Senate Committee on Finance;
• Senate Committee on Commerce, Science and Transportation;
• Senate Committee on Homeland Security and Governmental Affairs;
• House Committee on Appropriations; and
• House Committee on Oversight and Government Reform.
Bureau of the Census, Department of Commerce.
Notice of public meeting.
The Bureau of the Census (U.S. Census Bureau) is giving notice of a meeting of the Federal Economic Statistics Advisory Committee (FESAC). The Committee will advise the Directors of the Economics and Statistics Administration's (ESA) two statistical agencies, the Bureau of Economic Analysis (BEA) and the Census Bureau, and the Commissioner of the U.S. Department of Labor's Bureau of Labor Statistics (BLS) on statistical methodology and other technical matters related to the collection, tabulation, and analysis of federal economic statistics. Last minute changes to the agenda are possible, which could prevent giving advance public notice of schedule adjustments.
December 9, 2016. The meeting will begin at approximately 9:00 a.m. and adjourn at approximately 4:30 p.m.
The meeting will be held at the U.S. Census Bureau Conference Center, 4600 Silver Hill Road, Suitland, MD 20746.
James R. Spletzer, Designated Federal Official, Department of Commerce, U.S. Census Bureau, Research and Methodology Directorate, Room 5K019, 4600 Silver Hill Road, Washington, DC 20233, telephone 301-763-4069, email:
Members of the FESAC are appointed by the Secretary of Commerce. The Committee advises the Directors of the BEA, the Census Bureau, and the Commissioner of the Department of Labor's BLS, on statistical methodology and other technical matters related to the collection, tabulation, and analysis of federal economic statistics. The Committee is established in accordance with the Federal Advisory Committee Act (Title 5, United States Code, Appendix 2).
The meeting is open to the public, and a brief period is set aside for public comments and questions. Persons with extensive questions or statements must submit them in writing at least three days before the meeting to the Designated Federal Official named above. If you plan to attend the meeting, please register by Thursday, December 1, 2016. You may access the online registration form with the following link:
This meeting is physically accessible to people with disabilities. Requests for sign language interpretation or other auxiliary aids should also be directed to the Designated Federal Official as soon as known, and preferably two weeks prior to the meeting.
Due to increased security and for access to the meeting, please call 301-763-9906 upon arrival at the Census Bureau on the day of the meeting. A photo ID must be presented in order to receive your visitor's badge. Visitors are not allowed beyond the first floor.
The Department of Commerce will submit to the Office of Management and Budget (OMB) for clearance the following proposal for collection of information under the provisions of the Paperwork Reduction Act (44 U.S.C. chapter 35).
Data users tell us that they need comprehensive and consistent data on investment by all private nonfarm businesses, by industry, by kind of investment,
(a) To provide estimates of capital expenditures for all private nonfarm sectors of the economy by 3-digit and selected 4-digit North American Industry Classification System (NAICS) levels;
(b) to base the survey on a probability sample that yields measures of the statistical reliability of the survey estimates;
(c) to develop a base survey to benchmark more frequent surveys on capital expenditures that do not have complete industry coverage;
(d) to produce annual enterprise-level data with the level of detail, coverage, and quality which previously was only available as part of the quinquennial economic census;
(e) to provide detail on capital expenditures for estimating the national income and product accounts, estimating the productivity of U.S. industries, evaluating fiscal and monetary policy, and conducting research using capital expenditures data; and
(f) to provide industry analysts with capital expenditures data for market analysis, economic forecasting, identifying business opportunities,
This request is for a revision to the currently approved collection and will cover the 2016 through 2018 ACES (conducted in fiscal years 2017 through 2019). A change from the previous ACES authorization is the addition of detailed capital expenditures by type of structure and type of equipment. These data, collected every five years, were last collected in the 2012 ACES and will be collected again in the 2017 ACES. Another change is the collection of survey data from both employer and non-employer companies solely through electronic reporting. All companies will receive a notification letter containing their User ID and password, and will be directed to report online through the Census Bureau's Business Help Site. The online reporting instruments are an electronic version of the paper data collection instruments that will no longer be used. We will no longer have paper forms but respondents have the ability to print an ACES worksheet to use as a guide and/or a record of their response once they have completed the survey.
In addition to capital expenditures, all employer businesses will be asked to provide sales and receipts information to calculate industry investment to sales ratios and to assist in verifying that consolidated company data are being reported. Asset and depreciation information, also collected, assists in measuring changes in the nation's capital stock estimates.
The capital expenditures data collected annually from a sample of non-employer businesses are intended to better represent the total capital expenditures activity of all firms.
The Census Bureau will collect and publish ACES data based on the 2012 NAICS. Industries in the survey will comprise 3-digit and 4-digit 2012 NAICS codes.
The ACES is an integral part of the Federal Government's effort to improve the quality and usefulness of National economic statistics. Federal agencies, including the Census Bureau, use these data to improve and supplement ongoing statistical programs.
The Census Bureau uses the ACES data to improve the quality of monthly economic indicators of investment. The Census Bureau's Value of New Construction Put in Place survey currently uses the ACES data to benchmark its industrial buildings data.
The Bureau of Economic Analysis (BEA) uses the ACES annual capital expenditures data for equipment and computer software to prepare estimates of private fixed investment, a major component of gross domestic product (GDP). BEA also uses these data to prepare estimates of investment by industry in the fixed assets accounts (FAAs). Investment in structures from the ACES are used by BEA to prepare the gross domestic output of the construction industries in GDP by industry. Data collected by ACES every five years on industry capital expenditures by type of structure and type of equipment are critical inputs for preparing benchmarked estimates of private fixed investment in the national income and product accounts (NIPA), the input-output accounts, and the FAAs.
The Federal Reserve Board (FRB) uses the ACES data to improve estimates of investment indicators for monetary policy. The Bureau of Labor Statistics (BLS) uses the ACES annual data to improve estimates of capital stocks for productivity analysis and the detailed types of structures and types of equipment data collected every five years to improve estimates of manufacturing multifactor productivity measures.
The Centers for Medicare and Medicaid Services uses the data for monitoring and evaluating the healthcare industries.
The Department of the Treasury uses the data in analysis of depreciation.
In addition, the ACES data provide industry analysts with capital expenditure data for market analysts, economic forecasting, identifying business opportunities, product development, and business planning.
The capital expenditures by type of structure and type of equipment are critical to ensuring the appropriateness of capital expenditures statistics in years detailed data by types of structures and types of equipment are not collected.
This information collection request may be viewed at
Written comments and recommendations for the proposed information collection should be sent within 30 days of publication of this notice to
The Port of Corpus Christi Authority, grantee of FTZ 122, submitted a notification of proposed production activity to the FTZ Board on behalf of voestalpine Texas, LLC (voestalpine), located in Portland, Texas. The notification conforming to the requirements of the regulations of the FTZ Board (15 CFR 400.22) was received on November 7, 2016.
voestalpine already has authority to produce hot briquetted iron using foreign-sourced iron ore pellets within Subzone 122T. The current request would add hot briquetted iron (HBI) by-products and foreign-status materials/components to the scope of authority. Pursuant to 15 CFR 400.14(b), additional FTZ authority would be limited to the specific foreign-status materials/components and specific by-products described in the submitted notification (as described below) and subsequently authorized by the FTZ Board.
Production under FTZ procedures could exempt voestalpine from customs duty payments on the foreign-status materials/components used in export production. On its domestic sales, voestalpine would be able to choose the duty rates during customs entry procedures that apply to the HBI by-products—iron sludge, recycled iron briquettes, direct reduction remet, and iron fines (duty free) for the foreign-status materials/components noted below and in the existing scope of authority. Customs duties also could possibly be deferred or reduced on foreign-status production equipment.
The materials which may be sourced from abroad include sodium bentonite and slaked lime (duty free).
Public comment is invited from interested parties. Submissions shall be addressed to the FTZ Board's Executive Secretary at the address below. The
A copy of the notification will be available for public inspection at the Office of the Executive Secretary, Foreign-Trade Zones Board, Room 21013, U.S. Department of Commerce, 1401 Constitution Avenue NW., Washington, DC 20230-0002, and in the “Reading Room” section of the FTZ Board's Web site, which is accessible via
For further information, contact Diane Finver at
On August 9, 2016, the Executive Secretary of the Foreign-Trade Zones (FTZ) Board docketed an application submitted by the Mississippi Coast Foreign Trade Zone, Inc., grantee of FTZ 92, requesting an additional site within Subzone 92B on behalf of Huntington Ingalls Industries. The existing subzone and the proposed site would be subject to the existing activation limit of FTZ 92.
The application was processed in accordance with the FTZ Act and Regulations, including notice in the
Pursuant to the authority delegated to the FTZ Board's Executive Secretary (15 CFR Sec. 400.36(f)), the application to expand Subzone 92B is approved, subject to the FTZ Act and the Board's regulations, including Section 400.13, and further subject to FTZ 92's 2,000-acre activation limit.
An application has been submitted to the Foreign-Trade Zones Board (the Board) by the Puerto Rico Trade & Export Company, grantee of FTZ 61, requesting subzone status for the facility of Aceros de América, Inc., located in San Juan, Puerto Rico. The application was submitted pursuant to the provisions of the Foreign-Trade Zones Act, as amended (19 U.S.C. 81a-81u), and the regulations of the Board (15 CFR part 400). It was formally docketed on November 10, 2016.
The proposed subzone (4.49 acres) is located at State Road #1, km 25.0, Quebrada Arenas Ward, San Juan. The proposed subzone would be subject to the existing activation limit of FTZ 61. No authorization for production activity has been requested at this time.
In accordance with the Board's regulations, Camille Evans of the FTZ Staff is designated examiner to review the application and make recommendations to the Executive Secretary.
Public comment is invited from interested parties. Submissions shall be addressed to the Board's Executive Secretary at the address below. The closing period for their receipt is December 27, 2016. Rebuttal comments in response to material submitted during the foregoing period may be submitted during the subsequent 15-day period to January 10, 2017.
A copy of the application will be available for public inspection at the Office of the Executive Secretary, Foreign-Trade Zones Board, Room 21013, U.S. Department of Commerce, 1401 Constitution Avenue NW., Washington, DC 20230-0002, and in the “Reading Room” section of the Board's Web site, which is accessible via
For further information, contact Camille Evans at
On August 16, 2016, the Executive Secretary of the Foreign-Trade Zones (FTZ) Board docketed an application submitted by the Northern Mississippi FTZ, Inc., grantee of FTZ 262, requesting subzone status subject to the existing activation limit of FTZ 262, on behalf of ASICS America Corporation in Byhalia, Mississippi.
The application was processed in accordance with the FTZ Act and Regulations, including notice in the
Pursuant to the authority delegated to the FTZ Board's Executive Secretary (15 CFR Sec. 400.36(f)), the application to establish Subzone 262C is approved, subject to the FTZ Act and the Board's regulations, including Section 400.13, and further subject to FTZ 262's 680-acre activation limit.
Enforcement and Compliance, International Trade Administration, Department of Commerce.
On July 12, 2016, the Department of Commerce (the Department) published the preliminary results of the administrative review of the antidumping duty order on certain large diameter carbon and alloy seamless standard, line, and pressure pipe (over 4
Effective November 16, 2016.
Peter Zukowski, AD/CVD Operations, Office I, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 1401 Constitution Avenue NW., Washington, DC 20230; telephone: (202) 482-0189.
On July 12, 2016, the Department published the
The merchandise subject to the order is certain large diameter carbon and alloy seamless standard, line, and pressure pipe (over 4
As noted in the
After issuing the
Because the Department received no comments after the
The Department has determined, and CBP shall assess, antidumping duties on all appropriate entries of subject merchandise in accordance with the final results of this review.
The following deposit requirements will be effective upon publication of the notice of final results of administrative review for all shipments of certain large diameter carbon and alloy seamless standard, line, and pressure pipe (over 4
This notice serves as a final reminder to importers of their responsibility under 19 CFR 351.402(f)(2) to file a certificate regarding the reimbursement of antidumping duties prior to liquidation of the relevant entries during this review period. Failure to comply with this requirement could result in the Secretary's presumption that reimbursement of antidumping duties occurred and the subsequent assessment of double antidumping duties.
This notice also serves as a reminder to parties subject to administrative protective order (APO) of their responsibility concerning the destruction of proprietary information disclosed under APO in accordance with 19 CFR 351.305(a)(3). Timely written notification of the return or destruction of APO materials or conversion to judicial protective order is hereby requested. Failure to comply with the regulations and terms of an APO is a sanctionable violation.
We are issuing and publishing these results in accordance with sections 751(a)(1) and 777(i)(1) of the Act.
Notice of issuance of an amended Export Trade Certificate of Review to California Pistachio Export Council (“CPEC”), Application No. 03-2A008.
The U.S. Department of Commerce issued an amended Export Trade Certificate of Review to CPEC on November 1, 2016.
Joseph E. Flynn, Director, Office of Trade and Economic Analysis (“OTEA”), International Trade Administration, by telephone at (202) 482-5131 (this is not a toll-free number) or email at
Title III of the Export Trading Company Act of 1982 (15 U.S.C. Sections 4001-21) authorizes the Secretary of Commerce to issue Export Trade Certificates of Review. The regulations implementing Title III are found at 15 CFR part 325 (2016). OTEA is issuing this notice pursuant to 15 CFR 325.6(b), which requires the Secretary of Commerce to publish a summary of the certification in the
1. Add the following companies as Members of the Certificate: ARO Pistachios, Inc., and Zymex Industries, Inc.
(a) ARO Pistachios, Inc.
(b) Keenan Farms, Inc.
(c) Monarch Nut Company
(d) Nichols Pistachio
(e) Primex Farms, LLC
(f) Setton Pistachio of Terra Bella, Inc.
(g) Horizon Marketing Agency in Common Cooperative Inc.
(h) Zymex Industries, Inc.
Enforcement and Compliance, International Trade Administration, Department of Commerce.
Every five years, pursuant to section 751(c) of the Tariff Act of 1930, as amended (“the Act”), the Department of Commerce (“the Department”) and the International Trade Commission automatically initiate and conduct a review to determine whether revocation of a countervailing or antidumping duty order or termination of an investigation suspended under section 704 or 734 of the Act would be likely to lead to continuation or recurrence of dumping or a countervailable subsidy (as the case may be) and of material injury.
The following Sunset Reviews are scheduled for initiation in December 2016 and will appear in that month's Notice of Initiation of Five-Year Sunset Reviews (“Sunset Reviews”).
The Department's procedures for the conduct of Sunset Reviews are set forth in 19 CFR 351.218. The Notice of Initiation of Five-Year (“Sunset”) Reviews provides further information regarding what is required of all parties to participate in Sunset Reviews.
Pursuant to 19 CFR 351.103(c), the Department will maintain and make available a service list for these proceedings. To facilitate the timely preparation of the service list(s), it is requested that those seeking recognition as interested parties to a proceeding contact the Department in writing within 10 days of the publication of the Notice of Initiation.
Please note that if the Department receives a Notice of Intent to Participate from a member of the domestic industry within 15 days of the date of initiation, the review will continue. Thereafter, any interested party wishing to participate in the Sunset Review must provide substantive comments in response to the notice of initiation no later than 30 days after the date of initiation.
This notice is not required by statute but is published as a service to the international trading community.
Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce.
The Department of Commerce (the Department) is conducting an administrative review of the antidumping duty order on carbon and certain alloy steel wire rod (wire rod) from Mexico. The period of review (POR) is October 1, 2014 through September 30, 2015. This review covers two producers/exporters of the subject merchandise: Deacero S.A.P.I. de C.V. (aka Deacero S.A. de C.V., hereinafter referred to as Deacero) and ArcelorMittal Las Truchas, S.A. de C.V. (AMLT). We preliminarily determine that Deacero made sales of subject merchandise at less than normal value (NV) during the POR. Additionally, we preliminarily determine that AMLT had no shipments during the POR. Interested parties are invited to comment on these preliminary results.
Effective November 16, 2016.
James Terpstra AD/CVD Operations, Office III, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 14th Street and Constitution Avenue NW., Washington, DC 20230; telephone 202-482-3965.
On December 3, 2015, the Department published a notice of initiation
The merchandise covered by the
On October 1, 2012, the Department determined that wire rod with an actual diameter of 4.75 mm to 5.00 mm (hereinafter referred to as narrow gauge wire rod) produced in Mexico and exported to the United States by Deacero was circumventing the
The Federal Circuit upheld the Department's finding in the
AMLT reported that it made no sales of subject merchandise during the POR.
The Department is conducting this review in accordance with section 751(a)(2) of the Tariff Act of 1930, as amended (the Act). Constructed export prices or export prices are calculated in accordance with section 772 of the Act. Normal value is calculated in accordance with section 773 of the Act.
For a full description of the methodology underlying our conclusions, see the Preliminary Decision Memorandum. A list of topics discussed in the Preliminary Decision Memorandum is included as an appendix to this notice. The Preliminary Decision Memorandum is a public document and is on file electronically via Enforcement and Compliance's Antidumping and Countervailing Duty Centralized Electronic Service System (ACCESS). ACCESS is available to registered users at
As a result of this review, we preliminarily determine that the weighted-average dumping margin for the POR is as follows:
Upon issuance of the final results, the Department shall determine, and CBP shall assess, antidumping duties on all appropriate entries covered by this review. For any individually examined respondents whose weighted-average dumping margin is above
In accordance with the Department's “automatic assessment” practice, for entries of subject merchandise during the POR produced by each respondent for which they did not know that their merchandise was destined for the United States, we will instruct CBP to liquidate unreviewed entries at the all-others rate if there is no rate for the intermediate company(ies) involved in the transaction. For a full discussion of this clarification,
We intend to issue instructions to CBP 15 days after publication of the final results of this review.
The following cash deposit requirements will be effective upon publication of the notice of final results of administrative review for all shipments of subject merchandise entered, or withdrawn from warehouse, for consumption on or after the publication of the final results of this administrative review, as provided by section 751(a)(2) of the Act: (1) The cash deposit rate for Deacero will be equal to the weighted-average dumping margin established in the final results of this administrative review; (2) for merchandise exported by manufacturers or exporters not covered in this administrative review but covered in a prior completed segment of the proceeding, the cash deposit rate will continue to be the company-specific rate published in the completed segment for the most recent period; (3) if the exporter is not a firm covered in this review, a prior review, or the original investigation, but the manufacturer is, the cash deposit rate will be the rate established in the completed segment for the most recent period for the manufacturer of the merchandise; and (4) the cash deposit rate for all other manufacturers or exporters will continue to be 20.11 percent, the all-others rate established in the investigation.
The Department intends to disclose to parties to this proceeding the calculations performed in reaching the preliminary results within five days of the date of publication of these preliminary results.
Interested parties who wish to request a hearing must submit a written request to the Assistant Secretary for Enforcement and Compliance, U.S. Department of Commerce, using Enforcement and Compliance's ACCESS system within 30 days of publication of this notice.
Unless the deadline is extended pursuant to section 751(a)(3)(A) of the Act and 19 CFR 351.213(h)(2), the Department will issue the final results of this administrative review, including the results of our analysis of the issues raised by the parties in their case briefs, within 120 days after issuance of these preliminary results.
This notice serves as a preliminary reminder to importers of their responsibility under 19 CFR 351.402(f)(2) to file a certificate regarding the reimbursement of antidumping duties prior to liquidation of the relevant entries during this review period. Failure to comply with this requirement could result in the Department's presumption that reimbursement of antidumping duties occurred and the subsequent assessment of double antidumping duties.
These preliminary results of review are issued and published in accordance with sections 751(a)(1) and 777(i)(1) of the Act.
Enforcement and Compliance, International Trade Administration, Department of Commerce.
On July 12, 2016, the Department of Commerce (the Department) published the preliminary results of the administrative review of the antidumping duty order on certain small diameter carbon and alloy seamless standard, line, and pressure pipe (under 4
Effective November 16, 2016.
Peter Zukowski, AD/CVD Operations, Office I, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 1401 Constitution Avenue NW., Washington, DC 20230; telephone: (202) 482-0189.
On July 12, 2016, the Department published the
The merchandise subject to the order is certain small diameter carbon and alloy seamless standard, line, and pressure pipe (under 4
As noted in the
After issuing the
Because the Department received no comments after the
The Department has determined, and CBP shall assess, antidumping duties on all appropriate entries of subject merchandise in accordance with the final results of this review.
The following deposit requirements will be effective upon publication of the notice of final results of administrative review for all shipments of certain small diameter carbon and alloy seamless standard, line, and pressure pipe (under 4
This notice serves as a final reminder to importers of their responsibility under 19 CFR 351.402(f)(2) to file a certificate regarding the reimbursement of antidumping duties prior to liquidation of the relevant entries during this review period. Failure to comply with this requirement could result in the Secretary's presumption that reimbursement of antidumping duties occurred and the subsequent assessment of double antidumping duties.
This notice also serves as a reminder to parties subject to administrative protective order (APO) of their responsibility concerning the destruction of proprietary information disclosed under APO in accordance with 19 CFR 351.305(a)(3). Timely written notification of the return or destruction of APO materials or conversion to judicial protective order is hereby requested. Failure to comply with the regulations and terms of an APO is a sanctionable violation.
We are issuing and publishing these results in accordance with sections 751(a)(1) and 777(i)(1) of the Act.
International Trade Administration, Department of Commerce.
Notice.
The United States Department of Commerce, International Trade Administration (ITA), is organizing a Trade Mission to Taiwan and Hong Kong, with an optional stop in Guangzhou (China), focused on Smart Technologies in the Information and Communication Technology Sector on April 24-28, 2017. The goal of this trade mission is to provide U.S. participants with first-hand market information and one-on-one meetings with technology partners in Taiwan, Hong Kong, and Guangzhou, including potential agents and distributors of smart technologies, so they can position themselves to enter or expand their presence in those markets.
The mission is intended to help expand U.S. exports to Hong Kong, Taiwan, and China for U.S. technology providers of smart transportation, smart building and financial technology (fintech). The mission will introduce these suppliers to business partners, industry representatives, and government officials in Taiwan and Hong Kong, with an optional stop in Guangzhou (for smart transportation and smart building only) to learn about
The trade mission offers a timely and cost effective way of engaging key stakeholders in the development of smart city projects in Greater China. Trade mission participants will have the opportunity to interact extensively with host government, private sector and Commercial Service (CS) officials in Taiwan and Hong Kong to discuss industry developments, business opportunities and market entry strategies. In addition, participants with smart transportation and smart building technologies may opt to receive similar briefing and meeting opportunities in Guangzhou, China for an additional cost.
In Taiwan, Hong Kong, and Guangzhou (optional), participants will meet with pre-screened distributors, corporate representatives, and other business partners and government organizations involved in the promotion of smart technologies. They will also attend market briefings by U.S. Commercial Service and Consulate officials, as well as round table discussions offering further opportunities to speak with local business and industry decision-makers.
All parties interested in participating in the trade mission to Taiwan, Hong Kong, and Guangzhou (Optional) must complete and submit an application package for consideration by the Department of Commerce. All applicants, on a staggered basis, will be evaluated on their ability to meet certain conditions and best satisfy the selection criteria as outlined below. U.S. companies or trade associations already doing business in Taiwan, Hong Kong, and China, as well as U.S. companies/trade associations seeking to enter those markets for the first time may apply. A minimum of 15 and maximum of 20 firms and/or trade associations will be selected to participate in the mission from the applicant pool.
After a firm or trade association has been selected to participate on the mission, a payment to the Department of Commerce in the form of a participation fee is required. The participation fee for the Trade Mission will be $3,700 for small or medium-sized enterprises (SME);
The mission fee does not include any personal travel expenses such as lodging, most meals, local ground transportation and air transportation. Delegate members will, however, be able to take advantage of U.S. Government rates for hotel rooms. Government fees and processing expenses to obtain visas are also not included in the mission costs. However, the Department of Commerce will provide instructions to each participant on the procedures required to obtain necessary business visas. Trade Mission members participate in the trade mission and undertake mission-related travel at their own risk. The nature of the security situation in a given foreign market at a given time cannot be guaranteed. The U.S. Government does not make any representations or guarantees as to the safety or security of participants. The U.S. Department of State issues U.S. Government international travel alerts and warnings for U.S. citizens available at
An applicant must submit a completed and signed mission application and supplemental application materials, including adequate information on the company's products and/or services, primary market objectives, and goals for participation. If the Department of Commerce receives an incomplete application, the Department may reject the application, request additional information, or take the lack of information into account when evaluating the applications.
Each applicant must also certify that the products and services it seeks to export through the mission are either produced in the U.S., or, if not, are marketed under the name of a U.S. firm and have at least fifty-one percent U.S. content. In the case of a trade association or organization, the applicant must certify that for each company to be represented by the association/organization, the products and/or services the represented company seeks to export are either produced in the U.S. or, if not, marketed under the name of a U.S. firm and have at least fifty-one percent U.S. content.
In addition, each applicant must:
• Certify that the products and services that it wishes to market through the mission would be in compliance
• Certify that it has identified to the Department of Commerce for its evaluation any business pending before the Department that may present the appearance of a conflict of interest;
• Certify that it has identified any pending litigation (including any administrative proceedings) to which it is a party that involves the Department of Commerce; and
• Sign and submit an agreement that it and its affiliates (1) have not and will not engage in the bribery of foreign officials in connection with a company's/participant's involvement in this mission, and (2) maintain and enforce a policy that prohibits the bribery of foreign officials.
In the case of a trade association/organization, the applicant must certify that each firm or service provider to be represented by the association/organization can make the above certifications.
• Suitability of the company's (or, in the case of a trade association or trade organization, represented companies') products or services to the market.
• Company's (or, in the case of a trade association or trade organization, represented companies') potential for business in the country and region, including likelihood of exports resulting from the mission.
• Consistency of the applicant's goals and objectives with the stated scope of the mission. Balance of company size, sector or subsector, and location may also be considered during the review process.
Referrals from political organizations and any documents containing references to partisan political activities (including political contributions) will be removed from an applicant's submission and not considered during the selection process.
Mission recruitment will be conducted in an open and public manner, including publication in the
Gemal Brangman, Trade Promotion Programs Team Lead, U.S. Department of Commerce, Washington, DC,
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of public meeting and webinar/conference call.
NMFS will hold a 2-day Atlantic Highly Migratory Species (HMS) Advisory Panel (AP) meeting in December 2016. The intent of the meeting is to consider options for the conservation and management of Atlantic HMS, specifically Amendment 5b to the 2006 Consolidated Atlantic HMS Fishery Management Plan (FMP). The meeting is open to the public.
The AP meeting and webinar will be held from 1:30 p.m. to 5:30 p.m. on Thursday, December 1, 2016, and from 8:30 a.m. to 11:30 a.m. on Friday, December 2, 2016.
The meeting will be held at the DoubleTree by Hilton Hotel, 8120 Wisconsin Avenue, Bethesda, MD 20814. The meeting presentations will also be available via WebEx webinar/conference call.
The meeting on Thursday, December 1, and Friday, December 2, 2016, will also be accessible via conference call and webinar. Conference call and webinar access information are available at:
Participants are strongly encouraged to log/dial in 15 minutes prior to the meeting. NMFS will show the presentations via webinar and allow public comment during identified times on the agenda.
Peter Cooper or Margo Schulze-Haugen at (301) 427-8503.
The Magnuson-Stevens Fishery Conservation and Management Act, 16 U.S.C. 1801
The AP has previously consulted with NMFS on: Amendment 1 to the Billfish FMP (April 1999); the HMS FMP (April 1999); Amendment 1 to the HMS FMP (December 2003); the Consolidated HMS FMP (October 2006); and Amendments 1, 2, 3, 4, 5a, 5b, 6, 7, 8, 9 and 10 to the 2006 Consolidated HMS FMP (April and October 2008, February and September 2009, May and September 2010, April and September 2011, March and September 2012, January and September 2013, April and September 2014, March and September 2015, March and September 2016), among other things.
The intent of this meeting is for NMFS to consult with the AP on the proposed management measures contained in Draft Amendment 5b to the 2006 Consolidated Atlantic HMS FMP, which proposes a range of management measures to prevent overfishing and rebuild dusky sharks. These measures are based on a recent stock assessment that determined dusky sharks—a prohibited species since 2000—are overfished and still experiencing overfishing. Draft Amendment 5b could affect any commercial fishermen with HMS permits, any recreational fishermen who catch sharks of any species, and any dealers who buy or sell sharks or shark products.
Additional information on the meeting and a copy of the draft agenda will be posted prior to the meeting at:
This meeting is physically accessible to people with disabilities. Requests for sign language interpretation or other auxiliary aids should be directed to
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of issuance of a Letter of Authorization.
In accordance with regulations implementing the Marine Mammal Protection Act (MMPA), as amended, notification is hereby given that a Letter of Authorization (LOA) has been issued to the City of Seattle's Department of Transportation (SDOT) for the take of eight species of marine mammals incidental to pile driving activities associated with the Elliot Bay Seawall Project (EBSP).
Effective for a period of one year from November 16, 2016.
The LOA and supporting documentation are available for review online at:
Stephanie Egger, Office of Protected Resources, NMFS, 301-427-8401.
Section 101(a)(5)(A) of the MMPA (16 U.S.C. 1361
Regulations governing the taking of harbor seals (
Pursuant to those regulations, NMFS issued an LOA, effective from October 22, 2013, through October 21, 2014, a second LOA, effective from October 22, 2014, through October 21, 2015, and a third LOA, effective October 22, 2015, through August 31, 2016. SDOT conducted activities as described, implemented the required mitigation methods, and conducted the required monitoring. NMFS announces here that it has issued a fourth LOA, effective for one year, beginning November 16, 2016.
According to prior monitoring reports, no marine mammals entered the Level A harassment zone during the first year of the project (2013-2014 LOA). Two marine mammals entered the Level A harassment zone during the second year (2014-2015 LOA), but work was stopped or not initiated until the animal left the Level A harassment zone. Six killer whales were observed in the Level A harassment zone during the third year of the project (2015-2016 LOA), but pile activity was not occurring at the time. Low-frequency cetaceans (
Pinnipeds are more likely to be present in the construction area and to approach more closely. However, California sea lions (the pinniped species with the most documented takes), rested on the mooring buoys during construction and throughout the entire monitoring period on most days. These mooring buoys are well outside the SDOT's Level A harassment zones (under NMFS' then-current thresholds) for all pinnipeds and occur approximately two miles from these zones. The total number of potentially harassed marine mammals was well below the authorized limits, with the exception of the California sea lion in the 2014-2015 LOA (Year 2 LOA). The reported take for California sea lions for the Year 2 LOA by Level B harassment only, exceeded the annually authorized level, and slightly exceeded the authorized level in the Year 1 LOA, but not in the 2015-2016 LOA (Year 3 LOA). Please see the monitoring reports at
Based on our review of monitoring to date, we revised take estimates by assuming an estimated daily exposure of up to seven California sea lions (as compared with five assumed in regulations).
This revised estimate of take constitutes 0.14 percent of the population of California sea lions, which is 0.09 percent greater than the estimated take in the rule, and is the same kind of take anticipated in the regulations. Accordingly, the anticipated taking remains consistent with the basis for our final rule determinations of negligible impact based on the total taking and of small numbers, and our subsistence findings for the specified activity.
In August 2016, NMFS released its Technical Guidance for Assessing the Effects of Anthropogenic Sound on Marine Mammal Hearing (Guidance), which established new thresholds for predicting auditory injury, which equates to Level A harassment under the MMPA. In the August 4, 2016,
In this case, SDOT submitted a timely request for an LOA that was determined to be adequate and complete prior to availability of the Guidance and indicated that they would need to receive their fourth (final) LOA (if issued) by fall 2016. The incidental take rule for SDOT's activities considered the potential for auditory injury to marine mammals, and concluded that injury would be unlikely to occur due to SDOT's mitigation measures and SDOT's observed success of those measures as implemented previously. As described in the preamble of the regulations (78 FR 63396), the SDOT calculated Level A harassment and the Level A harassment mitigation zones on the basis of NMFS' then-current thresholds for onset of P (
Following release of the Guidance, we considered the updated thresholds and found that the distances at which animals might be exposed to injury fall mostly within the mitigation zones, and therefore the likelihood of auditory injury of marine mammals is still low. However, to further reduce the likelihood in light of the Guidance, the SDOT will now implement a 61meter (m) exclusion zone for high frequency cetaceans and a 25 m exclusion zone for pinnipeds (inclusive of both phocids and otariids) during vibratory pile driving, which is larger than the PTS isopleth indicated by the Guidance for otariids. As an addition to their monitoring plan, the SDOT will use Internet sites that track whale activity in Puget Sound prior to and during monitoring shifts in anticipation of any cetacean that may enter the Level A/B harassment zones. In summary, we have considered the new Guidance and believe that the likelihood of injury is adequately addressed in the analysis and appropriate protective measures are in place in the LOA.
NMFS has issued an LOA to SDOT authorizing the Level B harassment of marine mammals incidental to pile driving activities associated with the EBSP at Seattle, WA. Take of marine mammals will be minimized through implementation of the following mitigation measures: (1) Limited impact pile driving; (2) containment of impact pile driving; (3) additional sound attenuation measures; (4) ramp-up of pile-related activities; (5) marine mammal exclusion zones; and (6) shutdown and delay procedures. SDOT will also conduct visual monitoring and underwater acoustic monitoring for mitigation and research purposes. Reports will be submitted to NMFS at the time of request for a renewal of the LOA, and a final comprehensive report, which will summarize all previous reports and assess cumulative impacts, will be submitted before the rule expires.
Issuance of this LOA takes into consideration the results of the monitoring reports as well as NMFS' Guidance on hearing impacts from anthropogenic acoustic sources. Based on that information and the information discussed in the rule making for the five-year regulations, the activities described under the LOA and the level of anticipated taking is consistent with the findings made for the total taking allowable under the regulations, the project activities will have a negligible impact on the affected marine mammal species or stocks and will not have an unmitigable adverse impact on their availability for subsistence uses.
National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice.
The Department of Commerce, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to take this opportunity to comment on proposed and/or continuing information collections, as required by the Paperwork Reduction Act of 1995.
Written comments must be submitted on or before January 17, 2017.
Direct all written comments to Jennifer Jessup, Departmental Paperwork Clearance Officer, Department of Commerce, Room 6616, 14th and Constitution Avenue NW., Washington, DC 20230 (or via the Internet at
Requests for additional information or copies of the information collection instrument and instructions should be directed to John Foster, (301) 427-8130 or
This request is for extension of a currently approved information collection. The Large Pelagic Fishing Survey consists of dockside and telephone surveys of recreational anglers for large pelagic fish (tunas, sharks, and billfish) in the Atlantic Ocean. The survey provides the National Marine Fisheries Service (NMFS) with information to monitor catch of bluefin tuna, marlin and other federally managed species. Catch monitoring in these fisheries and collection of catch and effort statistics for all pelagic fish is required under the
Dockside and telephone interviews are used. In lieu of telephone interviews, respondents may also provide information online via a Web tool.
Comments are invited on: (a) Whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information shall have practical utility; (b) the accuracy of the agency's estimate of the burden (including hours and cost) of the proposed collection of information; (c) ways to enhance the quality, utility, and clarity of the information to be collected; and (d) ways to minimize the burden of the collection of information on respondents, including through the use of automated collection techniques or other forms of information technology.
Comments submitted in response to this notice will be summarized and/or included in the request for OMB approval of this information collection; they also will become a matter of public record.
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of intent; request for comments.
NMFS announces its intent to issue exempted fishing permits (EFPs), scientific research permits (SRPs), display permits, letters of acknowledgment (LOAs), shark research fishery permits, and chartering permits for Atlantic highly migratory species (HMS) in 2017. EFPs and related permits would authorize collection of a limited number of tunas, swordfish, billfishes, and sharks (collectively known as HMS) from Federal waters in the Atlantic Ocean, Caribbean Sea, and Gulf of Mexico for the purposes of scientific data collection, bycatch research, public display, and to evaluate the efficacy of environmental clean-up efforts, among other things. LOAs acknowledge that scientific research activity aboard a scientific research vessel is being conducted. Chartering permits allow the owner of a U.S. fishing vessel to fish under a chartering arrangement, which is a contract or agreement between a U.S. vessel owner and a foreign entity by which the control, use, or services of a vessel are secured for a period of time for fishing for Atlantic HMS on the high seas or in the Exclusive Economic Zone of other nations. Generally, EFPs and related permits would be valid from the date of issuance through December 31, 2017, unless otherwise specified, subject to the terms and conditions of individual permits.
Written comments on these activities received in response to this notice will be considered by NMFS when issuing EFPs and related permits and must be received on or before December 16, 2016.
Comments may be submitted by any of the following methods:
•
•
Craig Cockrell, phone: (301) 427-8503.
Issuance of EFPs and related permits are necessary because HMS regulations (
EFPs and related permits are issued under the authority of the Magnuson-Stevens Fishery Conservation and Management Reauthorization Act (Magnuson-Stevens Act) (16 U.S.C. 1801
While scientific research is exempt under MSA, scientific research is not exempt from regulation under ATCA. Therefore, NMFS issues SRPs which authorize researchers to collect HMS from bona fide research vessels for collection of species managed under this statute (
EFPs are issued to researchers collecting ATCA and Magnuson-Stevens Act-managed species while conducting research from commercial or recreational fishing vessels. Examples of research conducted under EFPs include collection of young-of-the-year bluefin tuna for genetic research; conducting billfish larval tows from private vessels to determine billfish habitat use, life history, and population structure; determining catch rates and gear characteristics of the swordfish buoy gear fishery and the green-stick tuna fishery; and tagging sharks caught on commercial or recreational fishing gear to determining post-release mortality rates.
NMFS is also seeking public comment on its intent to issue display permits for the collection of sharks and other HMS for public display in 2017. Collection of sharks and other HMS sought for public display in aquaria often involves collection when the commercial fishing seasons are closed, collection of otherwise prohibited species (
The majority of EFPs and related permits described in this annual notice relate to scientific sampling and tagging of Atlantic HMS within existing quotas and the impacts of the activities have been previously analyzed in various environmental assessments and environmental impact statements for Atlantic HMS. NMFS intends to issue these permits without additional opportunity for public comment beyond what is provided in this notice. Occasionally, NMFS receives applications for research activities that were not anticipated, or for research that is outside the scope of general scientific sampling and tagging of Atlantic HMS, or rarely, for research that is particularly controversial. Should NMFS receive such applications, NMFS will provide additional opportunity for public comment, consistent with the regulations at 50 CFR 600.745.
In 2016, as in recent years, NMFS received several requests from researchers who were collaborating with the research group OCEARCH to conduct shark research. However, later in the year, NMFS also received an application from OCEARCH indicating its intent to conduct shark research in collaboration with a number of scientists. Specifically, OCEARCH indicated its intent to coordinate all shark research it was involved in rather than require each individual scientist to apply for and receive their own EFP or SRP. In July 2016, NMFS issued an SRP to OCEARCH to tag and collect tissue samples from a variety sharks in Federal waters, including white, tiger, great hammerhead, smooth hammerhead, bull, sand tiger, shortfin mako, longfin mako, oceanic whitetip, blue, silky, and Caribbean reef sharks. Among other research conducted under this permit, eight juvenile white sharks were tagged with satellite or “smart position only” tags off New York in August. Because the original permit provided authorization to tag only eight white sharks, and because there were still several more research trips planned, at the request of the research group, NMFS amended the permit to add an additional 25 white sharks in late August. In mid-September, OCEARCH moved to Federal waters off the coast of Massachusetts and began their tagging and collection activities. Earlier in 2016, because the Commonwealth of Massachusetts was in the process of conducting a mark-recapture study to assess the population and movement pattern of white sharks in their state waters, the Commonwealth of Massachusetts denied OCEARCH access to state waters. Once OCEARCH began conducting research in Federal waters just outside of Massachusetts state waters, the state and other organizations expressed concern regarding the potential impact of OCEARCH's tagging activities on the mark-recapture study. If OCEARCH requests another group collaboration permit in 2017 or if individual researchers request the addition of OCEARCH on their permit in 2017, NMFS may issue a consolidated permit for all researchers utilizing this platform and would consider the concerns regarding the mark-recapture study, any concerns expressed during the comment period of this notice, and any other relevant information when deciding to issue the permit and associated permit conditions. Note, however, that the recent final rule modifying archival tag permitting and reporting requirements (August 19, 2016, 81 FR 55376) may mean that an EFP or SRP may no longer be needed for OCEARCH tagging activities as archival tagging activities, which is a primary focus of OCEARCH research, no longer require written authorization from NMFS.
In 2017, NMFS may once again receive an application for an EFP regarding purse seine fishing for Atlantic bluefin tuna. NMFS provided such an EFP to a purse seine vessel in 2014 and 2015 to study bycatch of large medium Atlantic bluefin tuna during otherwise authorized purse seine fishing operations. Specifically, the EFPs exempted the vessel owner from the retention limits on large medium BFT during otherwise authorized fishing operations. NMFS last issued a notice of intent regarding a potential purse seine EFP in 2014 (79 FR 63896, October 27, 2014), and did not receive any comments. NMFS issued the EFP for the 2015 fishing season on June 5, exempting the vessel from the size limit, with the following terms and conditions: (1) Mandatory observer coverage on all trips, (2) all dead bluefin tuna at haul back must be available to observers for sampling, (3) sub-legal
Compared to the dead discards that occurred in 2013, while fishing under an EFP in 2014 and 2015, the overall reduction in dead discards was 69 and 64 percent, respectively. In 2016, NMFS received a similar application to the 2015 request but, as of preparation of this notice, NMFS had not issued a 2016 EFP because the vessel to be used for the exempted fishing had not been issued a valid 2016 Atlantic Tunas permit in the Purse Seine category, and thus no otherwise authorized fishing could occur warranting a study of associated bycatch. NMFS may receive a similar request for an EFP in 2017 and requests comments, via this notice, on the continuation of such an EFP with similar terms and conditions should the permit holder have a properly permitted Purse Seine vessel. If such an application requests exemptions that are significantly different than those provided in the 2014 and 2015 permits, NMFS will provide additional opportunity for public comment.
NMFS is also requesting comments on chartering permits considered for issuance in 2017 to U.S. vessels fishing for HMS while operating under chartering arrangements with foreign countries. NMFS has not issued any chartering permits since 2004. A chartering arrangement is a contract or agreement between a U.S. vessel owner and a foreign entity by which the control, use, or services of a vessel are secured for a period of time for fishing for Atlantic HMS. Before fishing under a chartering arrangement, the owner of the U.S. fishing vessel must apply for a chartering permit and must also have been issued all other appropriate permits. The vessel chartering regulations can be found at 50 CFR 635.5(a)(4) and 635.32(e).
In addition, Amendment 2 to the 2006 Consolidated HMS Fishery Management Plan (FMP) implemented a shark research fishery. This research fishery is conducted under the auspices of the exempted fishing permit program. Shark research fishery permit holders assist NMFS in collecting valuable shark life history and other scientific data required in shark stock assessments. Since the shark research fishery was established in 2008, the research fishery has allowed for: The collection of fishery dependent data for current and future stock assessments; the operation of cooperative research to meet NMFS' ongoing research objectives; the collection of updated life-history information used in the sandbar shark (and other species) stock assessment; the collection of data on habitat preferences that might help reduce fishery interactions through bycatch mitigation; the evaluation of the utility of the mid-Atlantic closed area on the recovery of dusky sharks; and the collection of hook-timer and pop-up satellite archival tag information to determine at-vessel and post-release mortality of dusky sharks. Fishermen who wish to participate must fill out an application for a shark research permit under the exempted fishing program. Shark research fishery participants are subject to 100-percent observer coverage. All non-prohibited shark species brought back to the vessel dead must be retained and will count against the appropriate quotas of the shark research fishery participant. During the 2016 shark research fishery, all participants were limited to a very small number of dusky shark mortalities on a regional basis. Once the number of mortalities occurs in a specific region all shark research fishery activities must stop within that region. Also, participants are limited to two sets per trip with, one set limited to 150 hooks and the second set limited to 300 hooks. All participants are also limited to a maximum of 500 hooks onboard the vessel with on a shark research fishery trip. A
The authorized number of species for 2016, as well as the number of specimens collected in 2015, is summarized in Table 1. The number of specimens collected in 2016 will be available when all 2016 interim and annual reports are submitted to NMFS. In 2015, the number of specimens collected was less than the number of authorized specimens for all permit types, other than SRPs issued for shark research. The slightly higher numbers (21 sharks) are attributed to slightly more interactions with Atlantic sharpnose sharks on longline gear than anticipated. It is difficult to control the number and species of animals caught when using this gear type. These 21 sharks account for approximately 0.1 percent of the 57.2-mt ww quota available for the collection of most shark species under EFPs and related permits. Atlantic sharpnose sharks were determined to be not overfished and not experiencing overfishing in a 2013 stock assessment. Given the status of the species, the small number of Atlantic sharpnose sharks harvested above the authorized level, and the fact that the total number of sharks harvested across all permits is still less than the overall quota, this overharvest is not expected to have negative ecological impacts on the stock.
In all cases, mortality associated with an EFP, SRP, Display Permit, or LOA (except for larvae) is counted against the appropriate quota. NMFS issued a total of 36 EFPs, SRPs, display permits, and LOAs in 2015 for the collection of HMS and a total of 5 shark research fishery permits. As of October 4, 2016, NMFS has issued a total of 39 EFPs, SRPs, display permits, and LOAs and a total of 5 shark research fishery permits.
Final decisions on the issuance of any EFPs, SRPs, display permits, shark research fishery permits, and chartering permits will depend on the submission of all required information about the proposed activities, NMFS' review of public comments received on this notice, an applicant's reporting history on past permits, if vessels or applicants were issued any prior violations of marine resource laws administered by NOAA, consistency with relevant NEPA documents, and any consultations with appropriate Regional Fishery Management Councils, states, or Federal agencies. NMFS does not anticipate any significant environmental impacts from the issuance of these EFPs as assessed in the 1999 FMP, the 2006 Consolidated HMS FMP and its amendments, the Environmental Assessment for the 2012 Swordfish Specifications, and the Environmental Assessment for the 2015 Final Bluefin Tuna Quota and Atlantic Tuna Fisheries Management Measures.
16 U.S.C. 971
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of public meetings.
The North Pacific Fishery Management Council (Council) and its advisory committees will meet December 6 through December 14, 2016 in Anchorage, AK.
The Council and its advisory committees will hold meetings Tuesday, December 6 through Wednesday, December 14, 2016. See
The meeting will be held at the Anchorage Hilton Hotel, 500 W. 3rd Ave., Anchorage, AK 99501.
David Witherell, Council staff; telephone: (907) 271-2809.
The Council will begin its plenary session at 8 a.m. in the Aleutian Room on Thursday, December 8, continuing through Wednesday, December 14, 2016. The Scientific and Statistical Committee (SSC) will begin at 8 a.m. in the King Salmon/Iliamna Room on Tuesday, December 6 and continue through Friday December 9, 2016. The Council's Advisory Panel (AP) will begin at 8 a.m. in the Dillingham/Katmai Room on Wednesday December 7, and continue through Sunday, December 11, 2016. The Charter Halibut Management Committee will meet on Tuesday, December 6, 2016 (room to be determined) from 9 a.m. to 12 p.m. The Recreational Quota Entity Committee will meet on Tuesday, December 6, 2016, from 1 p.m. to 5 p.m. (room to be determined). The Ecosystem Committee will meet on Wednesday, December 7, 2016, from 9 a.m. to 12 p.m. (room to be determined). The Enforcement Committee will meet on Wednesday, December 7, 2016, from 1 p.m. to 4 p.m. (room to be determined).
The Advisory Panel will address most of the same agenda issues as the Council except B reports.
The SSC agenda will include the following issues:
In addition to providing ongoing scientific advice for fishery management decisions, the SSC functions as the Councils primary peer review panel for scientific information as described by the Magnuson-Stevens Act section 302(g)(1)(e), and the National Standard 2 guidelines (78 FR 43066). The peer review process is also deemed to satisfy the requirements of the Information Quality Act, including the OMB Peer Review Bulletin guidelines.
The Agenda is subject to change, and the latest version will be posted at
These meetings are physically accessible to people with disabilities. Requests for sign language interpretation or other auxiliary aids should be directed to Shannon Gleason at (907) 271-2809 at least 7 working days prior to the meeting date.
Department of Defense.
Notice of meeting.
The Department of Defense is publishing this notice to announce the following Federal Advisory Committee meeting of the Judicial Proceedings Since Fiscal Year 2012 Amendments Panel (“the Judicial Proceedings Panel” or “the Panel”). The meeting is open to the public.
A meeting of the Judicial Proceedings Panel will be held on Friday, December 9, 2016. The public session will begin at 9:00 a.m. and end at 4:30 p.m.
The location of the public meeting is yet to be determined, but will be posted on the JPP Web site at
Ms. Julie Carson, Judicial Proceedings Panel, One Liberty Center, Suite 150, 875 N. Randolph Street, Arlington, Virginia 22203. Email:
This public meeting is being held under the provisions of the Federal Advisory Committee Act of 1972 (5 U.S.C., Appendix, as amended), the Government in the Sunshine Act of 1976 (5 U.S.C. 552b, as amended), and 41 CFR 102-3.150.
National Center for Education Statistics (NCES), Department of Education (ED).
Notice.
In accordance with the Paperwork Reduction Act of 1995 (44 U.S.C. chapter 3501
Interested persons are invited to submit comments on or before December 16, 2016.
To access and review all the documents related to the information collection listed in this notice, please use
For specific questions related to collection activities, please contact NCES Information Collections at
The Department of Education (ED), in accordance with the Paperwork Reduction Act of 1995 (PRA) (44 U.S.C. 3506(c)(2)(A)), provides the general public and Federal agencies with an opportunity to comment on proposed, revised, and continuing collections of information. This helps the Department assess the impact of its information collection requirements and minimize the public's reporting burden. It also helps the public understand the Department's information collection requirements and provide the requested data in the desired format. ED is soliciting comments on the proposed information collection request (ICR) that is described below. The Department of Education is especially interested in public comment addressing the following issues: (1) Is this collection necessary to the proper functions of the Department; (2) will this information be processed and used in a timely manner; (3) is the estimate of burden accurate; (4) how might the Department enhance the quality, utility, and clarity of the information to be collected; and (5) how might the Department minimize the burden of this collection on the respondents, including through the use of information technology. Please note that written comments received in response to this notice will be considered public records.
Office of Fossil Energy, Department of Energy.
Notice of orders.
The Office of Fossil Energy (FE) of the Department of Energy gives notice that during September 2016, it issued orders granting authority to import and export natural gas, to import and export liquefied natural gas (LNG), and vacating prior authority. These orders are summarized in the attached appendix and may be found on the FE Web site at
They are also available for inspection and copying in the U.S. Department of Energy (FE-34), Division of Natural Gas Regulation, Office of Regulation and International Engagement, Office of Fossil Energy, Docket Room 3E-033, Forrestal Building, 1000 Independence Avenue SW., Washington, DC 20585, (202) 586-9478. The Docket Room is open between the hours of 8:00 a.m. and 4:30 p.m., Monday through Friday, except Federal holidays.
Office of Nonproliferation and Arms Control, Department of Energy.
Proposed subsequent arrangement.
This document is being issued under the authority of the Atomic Energy Act of 1954, as amended. The Department is providing notice of a proposed subsequent arrangement under Article 6 paragraph 2 of the Agreement for Cooperation Between the Government of the United States of America and the Government of the Argentine Republic Concerning Peaceful Uses of Nuclear Energy.
This subsequent arrangement will take effect no sooner than December 1, 2016.
Mr. Richard Goorevich, Office of Nonproliferation and Arms Control, National Nuclear Security Administration, Department of Energy. Telephone: 202-586-0589 or email:
This subsequent arrangement concerns the alteration in form or content of 17,729 g of U.S.-origin low enriched uranium (LEU), 3,502g of which is in the isotope of U-235 (19.75 percent enrichment), in cartridges containing filters, located at Ezeiza Radioactive Management Area (AGE), and 19,849g of U.S.-origin LEU, 3,925g of which is in the isotope ofU-235 (19.77 percent enrichment), contained in filters, located at the Fission Plant. Comision Nacional de Energia Atomica (CNEA) plans to recover and purify the slightly irradiated U.S.-origin LEU inventories held in filters of the Mo-99 production plant into a product to be used in the manufacturing of fuel elements and irradiation targets. The remaining radioisotope inventory will be set up for waste disposal. The recovery and purification will take place in the Radiochemical Laboratory Facility and the waste will be disposed in the AGE area. Both facilities are located in the Ezeiza Atomic Center. The material was obtained originally by CNEA from Y-12 pursuant to export licenses XSNM03348, XSNM3445, XSM3590, and XSNM3709. This will be an ongoing activity for the fission radioisotope production program at CNEA.
In accordance with section 131a. of the Atomic Energy Act of 1954, as amended, it has been determined that this subsequent arrangement concerning the alteration in form or content of nuclear material of United States origin will not be inimical to the common defense and security of the United States of America.
For the Department of Energy.
Office of Nonproliferation and Arms Control, Department of Energy.
Proposed subsequent arrangement.
This document is being issued under the authority of the Atomic Energy Act of 1954, as amended. The Department is providing notice of a proposed subsequent arrangement under the Agreement for Cooperation Between the United States of America and the Republic of Kazakhstan Concerning Peaceful Uses of Nuclear Energy and the Agreement for Cooperation in the Peaceful Uses of Nuclear Energy Between the United States of America and the European Atomic Energy Community.
This subsequent arrangement will take effect no sooner than December 1, 2016.
Mr. Richard Goorevich, Office of Nonproliferation and Arms Control, National Nuclear Security Administration, Department of Energy. Telephone: 202-586-30589 or email:
This subsequent arrangement concerns the retransfer of 2,794,512g of U.S.-origin enriched uranium oxide (UO2), containing 114,692g of the isotopeU-235 (less than five percent enrichment), from Ulba Metallurgical Plant in Ust-Kamengorsk, Kazakhstan, to Westinghouse Springfields Fuels Limited in Salwick, United Kingdom. The material has already been retransferred from Ulba to Westinghouse Springfields for storage.
In accordance with section 131a. of the Atomic Energy Act of 1954, as amended, it has been determined that this subsequent arrangement concerning the retransfer of nuclear material of United States origin will not be inimical to the common defense and security of the United States of America.
For the Department of Energy.
Department of Energy.
Notice of open meeting.
This notice announces a meeting of the Environmental Management Site-Specific Advisory Board (EM SSAB), Hanford. The Federal Advisory Committee Act requires that public notice of this meeting be announced in the
Wednesday, December 7, 2016—9:00 a.m.-5:00 p.m. Thursday, December 8, 2016—8:30 a.m.-3:00 p.m.
Pasco Red Lion, 2525 North 20th Avenue, Pasco, WA 99301.
Kristen Holmes, Federal Coordinator, Department of Energy Richland Operations Office, 825 Jadwin Avenue, P.O. Box 550, A7-75, Richland, WA, 99352; Phone: (509) 376-5803; or Email:
This notice identifies the Federal Energy Regulatory Commission (FERC or Commission) staff's revised schedule for the completion of the environmental impact statement (EIS) for PennEast Pipeline Company, LLC's (PennEast) PennEast Pipeline Project. The first notice of schedule, issued on March 29, 2016, identified December 16, 2016 as the EIS issuance date. Based on new route modifications filed by PennEast. The Commission staff intend to issue a notice to newly affected landowners. Commission staff has therefore revised the schedule for issuance of the final EIS.
If a schedule change becomes necessary, an additional notice will be provided so that the relevant agencies are kept informed of the project's progress.
In order to receive notification of the issuance of the EIS and to keep track of all formal issuances and submittals in specific dockets, the Commission offers a free service called eSubscription (
The Commission's October 31, 2016 order in the above-captioned proceeding
Take notice that a technical conference will be held on Thursday December 1, 2016 at 10:00 a.m., in a room to be designated at the offices of the Federal Energy Regulatory Commission, 888 First Street NE., Washington, DC 20426.
FERC conferences are accessible under section 508 of the Rehabilitation Act of 1973. For accessibility accommodations please send an email to
All interested persons and staff are permitted to attend. For further information please contact Omar Bustami at (202) 502-6214 or email Omar Bustami at
Take notice that the Commission has received the following Natural Gas Pipeline Rate and Refund Report filings:
The filings are accessible in the Commission's eLibrary system by clicking on the links or querying the docket number.
Any person desiring to intervene or protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Regulations (18 CFR 385.211 and § 385.214) on or before 5:00 p.m. Eastern time on the specified comment date. Protests may be considered, but intervention is necessary to become a party to the proceeding.
eFiling is encouraged. More detailed information relating to filing requirements, interventions, protests, service, and qualifying facilities filings can be found at:
Take notice that the Commission received the following electric rate filings:
The filings are accessible in the Commission's eLibrary system by clicking on the links or querying the docket number.
Any person desiring to intervene or protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00 p.m. Eastern time on the specified comment date. Protests may be considered, but intervention is necessary to become a party to the proceeding.
eFiling is encouraged. More detailed information relating to filing requirements, interventions, protests, service, and qualifying facilities filings can be found at:
Take notice that on November 2, 2016, pursuant to Rule 204 of the Federal Energy Regulatory Commission's (Commission) Rules of Practice and Procedure, 18 CFR 385.204 (2016), Tesoro Great Plains Gathering & Marketing LLC (Petitioner) filed a petition for temporary waiver of the tariff filing and reporting requirements of sections 6 and 20 of the Interstate Commerce Act and parts 341 and 357 of the Commission's regulations, as more fully explained in the petition.
Any person desiring to intervene or to protest this filing must file in accordance with Rules 211 and 214 of the Commission's Rules of Practice and Procedure (18 CFR 385.211 and 385.214 (2016)) on or before 5:00 p.m. Eastern time on the specified comment date. Protests will be considered by the Commission in determining the appropriate action to be taken, but will not serve to make protestants parties to the proceeding. Any person wishing to become a party must file a notice of intervention or motion to intervene, as appropriate. Such notices, motions, or protests must be filed on or before the comment date. Anyone filing a motion to intervene or protest must serve a copy of that document on the Petitioner.
The Commission encourages electronic submission of protests and interventions in lieu of paper using the
This filing is accessible on-line at
Take notice that the Commission has received the following Natural Gas Pipeline Rate and Refund Report filings:
Any person desiring to intervene or protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00 p.m. Eastern time on the specified comment date. Protests may be considered, but intervention is necessary to become a party to the proceeding.
Any person desiring to protest in any of the above proceedings must file in accordance with Rule 211 of the Commission's Regulations (18 CFR 385.211) on or before 5:00 p.m. Eastern time on the specified comment date.
The filings are accessible in the Commission's eLibrary system by clicking on the links or querying the docket number.
eFiling is encouraged. More detailed information relating to filing requirements, interventions, protests, service, and qualifying facilities filings can be found at:
On October 28, 2016, Essential Power Massachusetts, LLC (transferor) and Nautilus Hydro, LLC (transferee) filed an application for the transfer of license of the Gardners Falls Project No. 2334. The project is located on the Deerfield River in Franklin County, Massachusetts. The project does not occupy Federal lands.
The applicants seek Commission approval to transfer the license for the Gardners Falls Project from Essential Power Massachusetts, LLC to Nautilus Hydro, LLC.
Deadline for filing comments, motions to intervene, and protests: 30 days from the date that the Commission issues this notice. The Commission strongly encourages electronic filing. Please file comments, motions to intervene, and protests using the Commission's eFiling system at
Take notice that the following hydroelectric application has been filed
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All documents may be filed electronically via the Internet. See 18 CFR 385.2001(a)(1)(iii) and the instructions on the Commission's Web site at
The Commission's Rules of Practice and Procedure require all intervenors filing documents with the Commission to serve a copy of that document on each person whose name appears on the official service list for the project. Further, if an intervenor files comments or documents with the Commission relating to the merits of an issue that may affect the responsibilities of a particular resource agency, they must also serve a copy of the document on that resource agency.
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m. Individuals desiring to be included on the Commission's mailing list should so indicate by writing to the Secretary of the Commission.
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This is a supplemental notice in the above-referenced proceeding of SR South Loving LLC`s application for market-based rate authority, with an accompanying rate tariff, noting that such application includes a request for blanket authorization, under 18 CFR part 34, of future issuances of securities and assumptions of liability.
Any person desiring to intervene or to protest should file with the Federal Energy Regulatory Commission, 888 First Street NE., Washington, DC 20426, in accordance with Rules 211 and 214 of the Commission's Rules of Practice and Procedure (18 CFR 385.211 and 385.214). Anyone filing a motion to intervene or protest must serve a copy of that document on the Applicant.
Notice is hereby given that the deadline for filing protests with regard to the applicant's request for blanket authorization, under 18 CFR part 34, of future issuances of securities and assumptions of liability, is November 28, 2016.
The Commission encourages electronic submission of protests and interventions in lieu of paper, using the FERC Online links at
Persons unable to file electronically should submit an original and 5 copies of the intervention or protest to the Federal Energy Regulatory Commission, 888 First Street NE., Washington, DC 20426.
The filings in the above-referenced proceeding are accessible in the Commission's eLibrary system by clicking on the appropriate link in the above list. They are also available for electronic review in the Commission's Public Reference Room in Washington, DC. There is an eSubscription link on the Web site that enables subscribers to receive email notification when a document is added to a subscribed docket(s). For assistance with any FERC Online service, please email
Take notice that on October 31, 2016, Texas Eastern Transmission, LP (Texas Eastern), 5400 Westheimer Court, Houston, Texas 77056, filed in Docket No. CP17-7-000, an application pursuant to section 7(b) of the Natural Gas Act and Part 157 of the Commission's regulations, requesting approval to abandon certain offshore pipeline facilities located in federal offshore waters in the Gulf of Mexico near Louisiana. Specifically, Texas Eastern proposes to (i) abandon in place approximately 17.4 miles of a 20-inch diameter offshore supply lateral, designated as Line 41-B; (ii) abandon by removal metering and regulating station (“M&R”) 71474; (iii) abandon the receipt point at producer owned M&R 73548; and (iv) abandon by removal all related appurtenant facilities. Texas Eastern states abandonment of these facilities is required in light of a ruling by the United States Bankruptcy Court for the District of Texas related to Black Elk Energy Offshore Operations, LLC's requirement to remove its platform connected to Texas Eastern's Line 41-B. Texas Eastern also states that there will be no termination or reduction in firm service to any existing customers of Texas Eastern as a result of the proposed abandonment, all as more fully set forth in the application, which is on file with the Commission and open to public inspection. The filing may also be viewed on the web at
Any questions regarding this application should be directed to Lisa A. Connolly, General Manager, Rates & Certificates, Texas Eastern Transmission, LP, P.O. Box 1642, Houston, Texas 77251, phone: (713) 627-4102, or fax (713) 627-5947, or email:
Pursuant to section 157.9 of the Commission's rules, 18 CFR 157.9, within 90 days of this Notice the Commission staff will either: Complete its environmental assessment (EA) and place it into the Commission's public record (eLibrary) for this proceeding; or issue a Notice of Schedule for Environmental Review. If a Notice of Schedule for Environmental Review is issued, it will indicate, among other milestones, the anticipated date for the Commission staff's issuance of the final environmental impact statement (FEIS) or EA for this proposal. The filing of the EA in the Commission's public record for this proceeding or the issuance of a Notice of Schedule for Environmental Review will serve to notify federal and state agencies of the timing for the completion of all necessary reviews, and the subsequent need to complete all federal authorizations within 90 days of the date of issuance of the Commission staff's FEIS or EA.
There are two ways to become involved in the Commission's review of this project. First, any person wishing to obtain legal status by becoming a party to the proceedings for this project should, on or before the comment date stated below, file with the Federal Energy Regulatory Commission, 888 First Street NE., Washington, DC 20426, a motion to intervene in accordance with the requirements of the Commission's Rules of Practice and Procedure (18 CFR 385.214 or 385.211) and the Regulations under the NGA (18 CFR 157.10). A person obtaining party status will be placed on the service list maintained by the Secretary of the Commission and will receive copies of all documents filed by the applicant and by all other parties. A party must submit 7 copies of filings made with the Commission and must mail a copy to the applicant and to every other party in the proceeding. Only parties to the proceeding can ask for court review of Commission orders in the proceeding.
However, a person does not have to intervene in order to have comments considered. The second way to participate is by filing with the Secretary of the Commission, as soon as possible, an original and two copies of comments in support of or in opposition to this project. The Commission will consider these comments in determining the appropriate action to be taken, but the filing of a comment alone will not serve to make the filer a party to the proceeding. The Commission's rules require that persons filing comments in opposition to the project provide copies of their protests only to the party or parties directly involved in the protest.
Persons who wish to comment only on the environmental review of this project should submit an original and two copies of their comments to the Secretary of the Commission. Environmental commentors will be placed on the Commission's environmental mailing list, will receive copies of the environmental documents, and will be notified of meetings associated with the Commission's environmental review process. Environmental commentors will not be required to serve copies of filed documents on all other parties. However, the non-party commentors will not receive copies of all documents filed by other parties or issued by the Commission (except for the mailing of environmental documents issued by the Commission) and will not have the right to seek court review of the Commission's final order.
The Commission strongly encourages electronic filings of comments, protests and interventions in lieu of paper using the “eFiling” link at
There is an “eSubscription” link on the Web site that enables subscribers to receive email notification when a document is added to a subscribed
Take notice that the Commission received the following electric corporate filings:
Take notice that the Commission received the following exempt wholesale generator filings:
Take notice that the Commission received the following electric rate filings:
Description: ISO New England Inc., et. al. submits Installed Capacity Requirement, Hydro Quebec Interconnection Capability Credits and Related Values for the 2020/2021 Capacity Commitment Period.
The filings are accessible in the Commission's eLibrary system by clicking on the links or querying the docket number.
Any person desiring to intervene or protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00 p.m. Eastern time on the specified comment date. Protests may be considered, but intervention is necessary to become a party to the proceeding.
eFiling is encouraged. More detailed information relating to filing requirements, interventions, protests, service, and qualifying facilities filings can be found at:
On November 8, 2016, the Commission issued an order in Docket No. EL17-9-000, pursuant to section 206 of the Federal Power Act (FPA), 16 U.S.C. 824e (2012), instituting an investigation into the justness and reasonableness of Central Hudson Gas & Electric Corporation's, Tucson Electric Power Company's, UNS Electric, Inc.'s, and UniSource Energy Development Company's market-based rate authority in the Tucson Electric balancing authority area.
The refund effective date in Docket No. EL17-9-000, established pursuant to section 206(b) of the FPA, will be the date of publication of this notice in the
Any interested person desiring to be heard in Docket No. EL17-9-000 must file a notice of intervention or motion to intervene, as appropriate, with the Federal Energy Regulatory Commission, 888 First Street NE., Washington, DC 20426, in accordance with Rule 214 of the Commission's Rules of Practice and Procedure, 18 CFR 385.214 (2016), within 30 days of the date of issuance of the order.
Take notice that the Commission received the following electric rate filings:
The filings are accessible in the Commission's eLibrary system by clicking on the links or querying the docket number.
Any person desiring to intervene or protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00 p.m. Eastern time on the specified comment date. Protests may be considered, but intervention is necessary to become a party to the proceeding.
eFiling is encouraged. More detailed information relating to filing requirements, interventions, protests, service, and qualifying facilities filings can be found at:
The following notice of meeting is published pursuant to section 3(a) of the government in the Sunshine Act (Pub. L. 94-409), 5 U.S.C. 552b:
Federal Energy Regulatory Commission, DOE.
November 17, 2016, 10:00 a.m.
Room 2C, 888 First Street NE., Washington, DC 20426.
OPEN.
Agenda.
* NOTE—Items listed on the agenda may be deleted without further notice.
Kimberly D. Bose, Secretary, Telephone (202) 502-8400.
For a recorded message listing items struck from or added to the meeting, call (202) 502-8627.
This is a list of matters to be considered by the Commission. It does not include a listing of all documents relevant to the items on the agenda. All public documents, however, may be viewed on line at the Commission's Web site at
A free webcast of this event is available through
Immediately following the conclusion of the Commission Meeting, a press briefing will be held in the Commission Meeting Room. Members of the public may view this briefing in the designated overflow room. This statement is intended to notify the public that the press briefings that follow Commission meetings may now be viewed remotely at Commission headquarters, but will not be telecast through the Capitol Connection service.
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j. Kaukauna Utilities filed its request to use the Traditional Licensing Process on September 23, 2016. Kaukauna Utilities provided public notice of its request on October 25, 2016. In a letter dated November 8, 2016, the Director of the Division of Hydropower Licensing approved Kaukauna Utilities's request to use the Traditional Licensing Process.
k. With this notice, we are initiating informal consultation with: (a) The U.S. Fish and Wildlife Service and NOAA Fisheries under section 7 of the Endangered Species Act and the joint agency regulations thereunder at 50 CFR, Part 402; (b) NOAA Fisheries under section 305(b) of the Magnuson- Stevens Fishery Conservation and Management Act and implementing regulations at 50 CFR 600.920; and (c) the Wisconsin State Historic Preservation Officer, as required by section 106, National Historical Preservation Act, and the implementing regulations of the Advisory Council on Historic Preservation at 36 CFR 800.2.
l. With this notice, we are designating Kaukauna Utilities as the Commission's non-federal representative for carrying out informal consultation, pursuant to section 7 of the Endangered Species Act; section 305 of the Magnuson-Stevens Fishery Conservation and Management Act; and section 106 of the National Historic Preservation Act.
m. Kaukauna Utilities filed a Pre-Application Document (PAD; including a proposed process plan and schedule) with the Commission, pursuant to 18 CFR 5.6 of the Commission's regulations.
n. A copy of the PAD is available for review at the Commission in the Public Reference Room or may be viewed on the Commission's Web site (
o. The licensee states its unequivocal intent to submit an application for a new license for Project No. 10674. Pursuant to 18 CFR 16.8, 16.9, and 16.10 each application for a new license and any competing license applications must be filed with the Commission at least 24 months prior to the expiration of the existing license. All applications for license for this project must be filed by September 30, 2019.
p. Register online at
Environmental Protection Agency (EPA).
Notice.
Section 5(g) of the Toxic Substances Control Act (TSCA) requires
This action is directed to the public in general. As such, the Agency has not attempted to describe the specific entities that this action may apply to. Although others may be affected, this action applies directly to the submitters of the PMNs addressed in this action.
The docket for this action, identified by docket identification (ID) number EPA-HQ-OPPT-2016-0511, is available at
This document lists the statements of findings made by EPA after review of notices submitted under TSCA section 5(a) that certain new chemical substances or significant new uses are not likely to present an unreasonable risk of injury to health or the environment. This document presents statements of findings made by EPA during the period from September 20, 2016 to October 24, 2016.
TSCA section 5(a)(3) requires EPA to review a TSCA section 5(a) notice and make one of the following specific findings:
• The chemical substance or significant new use presents an unreasonable risk of injury to health or the environment;
• The information available to EPA is insufficient to permit a reasoned evaluation of the health and environmental effects of the chemical substance or significant new use;
• The information available to EPA is insufficient to permit a reasoned evaluation of the health and environmental effects and the chemical substance or significant new use may present an unreasonable risk of injury to health or the environment;
• The chemical substance is or will be produced in substantial quantities, and such substance either enters or may reasonably be anticipated to enter the environment in substantial quantities or there is or may be significant or substantial human exposure to the substance; or
• The chemical substance or significant new use is not likely to present an unreasonable risk of injury to health or the environment.
Unreasonable risk findings must be made without consideration of costs or other non-risk factors, including an unreasonable risk to a potentially exposed or susceptible subpopulation identified as relevant under the conditions of use. The term “conditions of use” is defined in TSCA section 3 to mean “the circumstances, as determined by the Administrator, under which a chemical substance is intended, known, or reasonably foreseen to be manufactured, processed, distributed in commerce, used, or disposed of.”
EPA is required under TSCA section 5(g) to publish in the
Anyone who plans to manufacture (which includes import) a new chemical substance for a non-exempt commercial purpose and any manufacturer or processor wishing to engage in a use of a chemical substance designated by EPA as a significant new use must submit a notice to EPA at least 90 days before commencing manufacture of the new chemical substance or before engaging in the significant new use.
The submitter of a notice to EPA for which EPA has made a finding of “not likely to present an unreasonable risk of injury to health or the environment” may commence manufacture of the chemical substance or manufacture or processing for the significant new use notwithstanding any remaining portion of the applicable review period.
In this unit, EPA provides the following information (to the extent that such information is not claimed as Confidential Business Information (CBI)) on the PMNs, MCANs and SNUNs for which, during this period, EPA has made findings under TSCA section 5(a)(3)(C) that the new chemical substances or significant new uses are not likely to present an unreasonable risk of injury to health or the environment:
• EPA case number assigned to the TSCA section 5(a) notice.
• Chemical identity (generic name, if the specific name is claimed as CBI).
• Web site link to EPA's decision document describing the basis of the “not likely to present an unreasonable risk” finding made by EPA under TSCA section 5(a)(3)(C).
15 U.S.C. 2601
Section 309(a) of the Clean Air Act requires that EPA make public its comments on EISs issued by other Federal agencies. EPA's comment letters on EISs are available at:
Federal Election Commission.
999 E Street NW., Washington, DC, (Ninth Floor).
This meeting will be open to the public.
Individuals who plan to attend and require special assistance, such as sign language interpretation or other reasonable accommodations, should contact Shelley E. Garr, Deputy Secretary, at (202) 694-1040, at least 72 hours prior to the meeting date.
Judith Ingram, Press Officer, Telephone: (202) 694-1220.
In accordance with section 10(a)(2) of the Federal Advisory Committee Act (Pub. L. 92-463), the Centers for Disease Control and Prevention (CDC), announces the following meeting of the aforementioned committee:
Centers for Disease Control and Prevention (CDC), Global Communications Center, Building 19, Classrooms 256/257, 1600 Clifton Road NE., Atlanta, Georgia 30329
Open to the public limited only by the space available. The meeting room will accommodate up to 40 people. Public participants should pre-register for the meeting as described below.
Members of the public that wish to attend this meeting in person should pre-register by submitting the following information by email, facsimile, or phone (see Contact Person for More Information) no later than 12:00 noon (EST) on Tuesday, December 6, 2016:
• Full Name
• Organizational Affiliation
• Complete Mailing Address
• Citizenship
• Phone Number or Email Address
Web conferencing information:
Web ID:
Dial in number: 888-942-9042 Participant passcode: 3979208
This Board is charged with providing advice and guidance to the Secretary, Department of Health and Human Services (HHS), the Assistant Secretary for Health (ASH), the Director, Centers for Disease Control and Prevention (CDC), and the Director, Office of Public Health Preparedness and Response (OPHPR), concerning strategies and goals for the programs and research within OPHPR, monitoring the overall strategic direction and focus of the OPHPR Divisions and Offices, and administration and oversight of peer review of OPHPR scientific programs. For additional information about the Board, please visit:
Day one of the meeting will cover briefings and BSC deliberation on the following topics: Interval updates from OPHPR Divisions and Offices; updates on OPHPR'S policy agenda; PHPR research agenda; CDC surveillance strategies; and BSC liaison representative updates to the Board highlighting organizational activities relevant to the OPHPR mission.
Day two of the meeting will cover briefings and BSC deliberation on the
Dometa Ouisley, Office of Science and Public Health Practice, Centers for Disease Control and Prevention, 1600 Clifton Road NE., Mailstop D-44, Atlanta, Georgia 30329-4027, Telephone: (404) 639-7450; Facsimile: (404)639-7977; Email:
The Director, Management Analysis and Services Office, has been delegated the authority to sign
In accordance with section 10(a)(2) of the Federal Advisory Committee Act (Pub. L. 92-463), the Centers for Disease Control and Prevention (CDC) announces the following meeting of the aforementioned committee:
This meeting is also accessible by Webinar:
The Director, Management Analysis and Services Office, has been delegated the authority to sign
Centers for Medicare & Medicaid Services, HHS.
Notice.
The Centers for Medicare & Medicaid Services (CMS) is announcing an opportunity for the public to comment on CMS' intention to collect information from the public. Under the Paperwork Reduction Act of 1995 (PRA), federal agencies are required to publish notice in the
Comments on the collection(s) of information must be received by the OMB desk officer by
When commenting on the proposed information collections, please reference the document identifier or OMB control number. To be assured consideration, comments and recommendations must be received by the OMB desk officer via one of the following transmissions:
OMB, Office of Information and Regulatory Affairs
To obtain copies of a supporting statement and any related forms for the proposed collection(s) summarized in this notice, you may make your request using one of following:
1. Access CMS' Web site address at
2. Email your request, including your address, phone number, OMB number, and CMS document identifier, to
3. Call the Reports Clearance Office at (410) 786-1326.
Reports Clearance Office at (410) 786-1326.
Under the Paperwork Reduction Act of 1995 (PRA) (44 U.S.C. 3501-3520), federal agencies must obtain approval from the Office of Management and Budget (OMB) for each collection of information they conduct or sponsor. The term “collection of information” is defined in 44 U.S.C. 3502(3) and 5 CFR 1320.3(c) and includes agency requests or requirements that members of the public submit reports, keep records, or provide information to a third party. Section 3506(c)(2)(A) of the PRA (44 U.S.C. 3506(c)(2)(A)) requires federal agencies to publish a 30-day notice in the
1.
Food and Drug Administration, HHS.
Notice.
The Center for Drug Evaluation and Research (CDER) in the Food and Drug Administration (FDA) is announcing the 2017 CDER Office of Pharmaceutical Quality (OPQ) Staff Experiential Learning Site Visit Program. The purpose of this document is to invite pharmaceutical companies interested in participating in this program to submit a site visit proposal to CDER's OPQ.
Submit either an electronic or written proposal to participate in this program by January 17, 2017. See section IV of this document for information on what to include in such proposals.
Janet Wilson, Center for Drug Evaluation and Research, Food and Drug Administration, 10903 New Hampshire Ave., Bldg. 75, Rm. 4642, Silver Spring, MD 20993-0002, 240-402-3969, email:
A critical part of the commitment by CDER to make safe and effective high-quality drugs available to the American public is gaining an understanding of all aspects of drug development and a drug's commercial life cycle, including the variety of drug manufacturing operations. To support this commitment, CDER has initiated various training and development programs, including the 2017 OPQ Staff Experiential Learning Site Visit Program. This site visit program is designed to offer experiential and firsthand learning opportunities that will provide OPQ staff with a better understanding of the pharmaceutical industry and its operations, as well as of the challenges that impact a drug's development program and commercial life cycle. The goal of these visits is to provide OPQ staff exposure to the drug development and manufacturing processes in industry; therefore, a tour of pharmaceutical company facilities is an integral part of the program.
In this site visit program, groups of OPQ staff—who have experience in a variety of backgrounds, including science, statistics, manufacturing, engineering and testing—will observe operations of commercial manufacturing, pilot plants, and testing over a 1- to 2-day period. To facilitate the learning process for OPQ staff, overview presentations by industry related to drug development and manufacturing may be provided, which may allow the participating sites to benefit by having an opportunity to showcase their technologies and manufacturing processes.
OPQ encourages companies engaging in the development and manufacturing of both drug substances and drug products to respond. However, please note that this site visit program is not intended to supplement or to replace a regulatory inspection,
Although observation of all aspects of drug development and production would be beneficial to OPQ staff, OPQ has identified a number of areas of particular interest to its staff. The following list identifies some of these areas but is not intended to be exhaustive or to limit industry response:
Selection of potential facilities will be based on the priorities developed for OPQ staff training, the facility's current regulatory status with FDA, and on consultation with the appropriate FDA district office. All travel expenses associated with this program will be the responsibility of OPQ; therefore, selection will be based on the availability of funds and resources for the fiscal year. OPQ will not provide financial compensation to the pharmaceutical site as part of this program.
Companies interested in offering a site visit or learning more about this site visit program should respond by submitting a proposal directly to Janet Wilson (see the
Pursuant to section 10(a) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of a meeting of the Advisory Committee to the Director, National Institutes of Health.
The meeting will be open to the public, with attendance limited to space available. Individuals who plan to attend and need special assistance, such as sign language interpretation or other reasonable accommodations, should notify the Contact Person listed below in advance of the meeting.
Any interested person may file written comments with the committee by forwarding the statement to the Contact Person listed on this notice. The statement should include the name, address, telephone number and when applicable, the business or professional affiliation of the interested person.
In the interest of security, NIH has instituted stringent procedures for entrance onto the NIH campus. All visitor vehicles, including taxicabs, hotel and airport shuttles will be inspected before being allowed on campus. Visitors will be asked to show one form of identification (for example, a government-issued photo ID, driver's license, or passport) and to state the purpose of their visit.
Information is also available on the Office of the Director, National Institutes of Health, home page:
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of the following meetings.
The meetings will be closed to the public in accordance with the provisions set forth in sections 552b(c)(4) and 552b(c)(6), Title 5 U.S.C., as amended. The grant applications and the discussions could disclose confidential trade secrets or commercial property such as patentable material, and personal information concerning individuals associated with the grant applications, the disclosure of which would constitute a clearly unwarranted invasion of personal privacy.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of a meeting of the Board of Scientific Counselors, National Institute of Dental and Craniofacial Research.
The meeting will be closed to the public as indicated below in accordance with the provisions set forth in section 552b(c)(6), Title 5 U.S.C., as amended for the review, discussion, and evaluation of individual intramural programs and projects conducted by the National Institute of Dental & Craniofacial Research, including consideration of personnel qualifications and performance, and the competence of individual investigators, the disclosure of which would constitute a clearly unwarranted invasion of personal privacy.
In the interest of security, NIH has instituted stringent procedures for entrance onto the NIH campus. All visitor vehicles, including taxicabs, hotel, and airport shuttles will be inspected before being allowed on campus. Visitors will be asked to show one form of identification (for example, a government-issued photo ID, driver's license, or passport) and to state the purpose of their visit.
Information is also available on the Institute's/Center's home page:
Pursuant to section 10(d) the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of the following meeting.
The meeting will be closed to the public in accordance with the provisions set forth in sections 552b(c)(4) and 552b(c)(6), Title 5 U.S.C., as amended. The grant applications and the discussions could disclose confidential trade secrets or commercial property such as patentable material, and personal information concerning individuals associated with the grant applications, the disclosure of which would constitute a clearly unwarranted invasion of personal privacy.
This notice is being published less than 15 days prior to the meeting due to the timing limitations imposed by the review and funding cycle.
Advisory Council on Historic Preservation.
Adoption of Policy Statement on Historic Preservation and Community Revitalization.
The Advisory Council on Historic Preservation (ACHP) adopted a Policy Statement on Historic Preservation and Community Revitalization.
The final policy was adopted, and went into effect, on October 26, 2016.
Charlene Dwin Vaughn, AICP, Assistant Director, Office of Federal Agency Programs, ACHP, at 202-517-0207, or
The Advisory Council on Historic Preservation (ACHP) is an independent agency, created by the National Historic Preservation Act (54 U.S.C. 300101 et seq), that promotes the preservation, enhancement, and productive use of our Nation's historic resources, and advises the President and Congress on national preservation policy.
Section 106 of the National Historic Preservation Act (Section 106), 54 U.S.C. 306108), requires Federal agencies to consider the effects of projects that require federal approval, that receive federal financial assistance, or that are carried out by federal agencies, on historic properties and provide the ACHP a reasonable opportunity to comment with regard to such projects. ACHP has issued the regulations that set forth the process through which Federal agencies comply with these duties. Those regulations are codified under 36 CFR part 800.
In March 2014, the ACHP issued the report entitled
As the ACHP explored options to implement the recommendations in the report, it was concluded in 2015 that the development of a policy statement would be appropriate to advance historic preservation principles. Therefore, the purpose of developing the Policy Statement on Historic Preservation and Community Revitalization is to ensure that preservation is considered as a tool that will assist federal, state, and local governments plan and implement revitalization projects and programs in a manner that will consider the reuse and rehabilitation of historic properties.
In 2014, the Chairman of the ACHP convened a Working Group to assist in developing a draft policy statement. Representatives of the Working Group included the U.S. Department of Housing and Urban Development (HUD), U.S. Department of Agriculture, U.S. Department of Health and Human Services, the National Park Service, the National Trust for Historic Preservation, the American Assembly, the Cleveland Restoration Society, Preservation Research Office, Historic Districts Council, Preservation Rightsizing Network, the Michigan State Historic Preservation Officer, and ACHP expert member Bradford White, Chair of the Working Group.
Following the development of the draft, the ACHP posted the proposed draft in the
Only thirteen (13) comments were submitted by the public on the draft policy statement. The majority of these commenters supported the draft and were eager for the ACHP to adopt the policy statement so that it could be implemented to advance local historic preservation. Four commenters, however, expressed concerns regarding a number of substantive issues and were basically critical about the ACHP's development of the draft policy. Major issues expressed by the four commenters included recommendations that the document should be revised to improve grammar and tone and references to the Section 106 process. They also took exception to the ACHP's use of flexible and programmatic solutions given their opinion that the ACHP had approved many contradictory systems over the years.
Other noteworthy comments made by the objectors to the draft policy statement included the following: (1) The sequencing of the principles needed to be changed; (2) best practices and case studies needed to be incorporated in the draft to illustrate the principles; (3) failure to encourage flexibility when applying the Secretary of Interior's Standards for Rehabilitation (Secretary Standards); (4) more communities needed to be encouraged to become Certified Local Governments (CLGs); (5) allow CLGs to determine the National Register eligibility of properties; (6) educate stakeholders about how to apply the principles in the policy statement; (7) revise the ACHP's regulations as they include a dated framework for problem-solving; (8) acknowledge the benefits of state and local tax credits to communities; (9) public-private partnerships should be creative and incentivize the revitalization of neighborhoods; (10) allow residents to identify the resources they care about; (11) the policy is overly concerned with buildings and properties instead of concepts of place and landscapes; (12) acknowledge the immense scale of challenges for vacant and distressed buildings nationwide; (13) present the principles in the format of a Section 106 document; (14) public subsidy of historic preservation projects must avoid reinvestment in unsustainable areas; (15) all mitigation should be creative; and (16) change the tile to “Community Revitalization and Historic Preservation.”
ACHP staff developed a Comment Matrix of the 104 substantive comments submitted by the 13 commenters. In addition to summarizing the comments and clarifying the ACHP's response, the
While Section 106 applies to most projects that meet the definition of undertaking as outlined in 36 CFR 800.16(y), “when the agency determines that the undertaking is a type of activity that does not have the potential to cause effects on historic properties, assuming such historic properties were present, the official has no further obligations under section 106.” 36 CFR 800.3(a)(1). Therefore, the commenter that suggested that the use of all federal dollars should require compliance with Section 106 did not consider this provision or the fact that a Section 106 program alternative may also exclude certain federal activities. Likewise, the recommendation that federal funds must be allocated to support the development of comprehensive planning and revitalization strategies is incorrect. While the ACHP agrees with this recommendation in theory, a federal agency like HUD or the Rural Development under the Department of Agriculture would have to adopt this concept into their grant programs.
The inclusion of references to Indian tribes in the policy statement was specifically requested by ACHP members. If they were excluded, the perspectives and concerns of Indian tribes would be minimized. Since Indian tribes are participants in the Section 106 consultations and provide expertise on the importance and significance of historic properties on tribal lands as well as historic properties located off-tribal lands which have religious and cultural significance to them, it is important that they be involved in the development of community revitalization strategies for communities located throughout the Nation.
Comments submitted asserting that the National Register criteria are viewed as an impediment, and restrict effective citizen engagement were not specifically addressed in the final policy statement. These comments and the related suggestions argue that Section 106 of the NHPA is a dated framework. This is beyond the scope of the development of this policy statement. However, it should be noted that Principle V is revised to allow communities to recognize the value of places that are important to local residents. In addition, Principle VII emphasizes the need for diverse citizen engagement, which encourages that all residents should participate in the identification of historic properties.
The Working Group determined that it was important to publish a current policy statement that reaffirmed the importance of historic preservation to the revitalization of all communities that must adapt to changing physical, social, and economic conditions. Federal urban policies disseminated since 2008 have not always consistently endorsed the importance of historic preservation in assistance programs. This policy statement will continue to promote the importance of federal leadership in historic preservation. Further, the policy statement will be continually updated to illustrate for stakeholders the application of the principles, and to educate citizens about the benefits of historic preservation as part of the revitalization of their communities. In collaboration with federal agencies and preservation organizations, the policy statement will be distributed to local, area, field, and regional staff so that the principles assist staff in planning and reviewing projects and developing new programs to help reverse the loss of historic properties as cities implement public-private programs throughout the community.
The policy statement, which represents the conclusion of the research and public outreach efforts of the Working Group, ACHP staff, and deliberation of its members, was adopted by the ACHP by an unassembled meeting vote on October 26, 2016. The final text of the policy statement is provided in Section II of this notice.
This is the final text of the policy, as adopted by the ACHP on October 26, 2016:
The 2010 U.S. Census revealed that, as a result of the significant decline in the economy beginning in 2008, an estimated 19 million properties were abandoned throughout the nation. As a result of the economic downturn, many buildings, in particular older and often historic properties, became vacant and abandoned. This has led to blighted conditions in many communities around the nation. Economists have compared the impacts of the economic downturn in 2008 to that of the Great Depression in the 1930s. Natural disasters, economic downturns, and the mortgage foreclosure crisis all occurred at the beginning of the 21st century, collectively eroding urban, rural, and tribal communities.
While these events resulted in significant economic impacts across the country, they accelerated declines in population, tax base, industry, jobs, and housing markets caused by structural changes to the economy. Impacts were most severe in the Midwest, Northeast, Mid-Atlantic, and the South. The estimated demolition of 200,000 properties exemplifies the extreme actions taken by many communities, resulting in the loss of residences, commercial buildings, and even entire neighborhoods. Many of the properties that were lost included historic buildings that were listed in or eligible for listing on the National Register of Historic Places. The focus of media attention on these issues centered on “legacy cities,” the term used to describe older, industrial communities. But research has revealed that suburban, rural, and tribal communities also have dealt with similar problems.
Communities identified as industrial centers were hit particularly hard and continue to struggle. These communities experienced shrinking population, declining property values, and high rates of residential vacancies and abandonments and required a holistic approach to bring about their revitalization.
In 1966, Congress passed the National Historic Preservation Act (NHPA) and declared that “the historical and cultural foundations of the nation should be preserved in order to give a sense of orientation to the American people.” It further stated that “in the face of ever increasing extensions of urban centers, highways, and residential, commercial, and industrial developments, the present governmental
The congressional findings in the NHPA remain applicable today, particularly since the economic crisis of 2008. The Advisory Council on Historic Preservation (ACHP), established by the NHPA to advise the President and Congress on matters relating to historic preservation, considers local community revitalization critical to stabilizing these economically depressed communities. In overseeing federal project reviews required by Section 106 of the NHPA, the ACHP has seen that historic preservation reviews are often not completed before federal funds are allocated. Further, the funds are often ineffectively or inappropriately used to manage redevelopment in struggling communities. Preservation options are not considered, and opportunities to reuse existing assets are missed because of the severity of the issues confronted by communities.
The ACHP sees a need to raise awareness of the potential community revitalization benefits from programs authorized by the NHPA and to provide an alternative framework for communities that have needs beyond the traditional historic preservation practices. To confront the challenge, community revitalization plans must be developed that address the disposition of vacant and abandoned properties, promote rehabilitation, create affordable housing, direct growth to target areas that have the infrastructure, and utilize new infill construction to stabilize neighborhoods or develop mixed use projects. Such plans can benefit from using the Secretary of the Interior's Standards for the Treatment of Historic Properties (1995) (Secretary's Standards), as appropriate, as the framework for revitalizing housing, infrastructure, and commercial facilities. Further, involving historic preservation professionals who meet the Secretary's Standards as employees or contractors of local, regional, and state agencies can aid in developing and implementing effective community revitalization plans that build on historic assets.
In March 2014, the ACHP issued a report entitled
In accordance with Section 202 of the NHPA, the ACHP is issuing this Policy Statement to provide federal agencies; the individuals, organizations, and governments that apply for federal assistance; and their public and private partners with a flexible and creative approach to developing local community revitalization plans that involve historic properties. Likewise, the Policy Statement is intended to equip residents and community organizations with information on available tools and assist them in creating realistic strategies to integrate into revitalization plans the conservation and rejuvenation of the places and properties that define their neighborhoods.
A major goal of the Policy Statement is assisting federal agencies and their grantees and applicants, State Historic Preservation Officers (SHPOs), Tribal Historic Preservation Officers (THPOs), Certified Local Governments (CLGs), and state and local governments in complying with the requirements of Section 106 of the NHPA. Section 106 requires federal agencies to take into account the effects of their undertakings on historic properties and afford the ACHP a reasonable opportunity to comment. With a predictable and consistent policy framework, or an alternative framework developed to address the unique circumstances faced by a community, federal agencies and applicants will be encouraged to integrate historic preservation principles in holistic community revitalization strategies. The policy acknowledges that consideration of alternatives to avoid or minimize harm to historic properties is essential when planning community revitalization projects. Further, by engaging varied stakeholders in the early stages of project planning, community revitalization projects can achieve multiple community goals.
This Policy Statement builds on an earlier ACHP Policy Statement on Affordable Housing issued in 2006 (
An underlying premise of the Policy Statement is the essential need for and value of local inventories and surveys, particularly in older neighborhoods that may be listed in or eligible for listing in the National Register of Historic Places (National Register) as historic districts. Only when local officials and the public are aware of the historic properties in their communities can they make informed decisions about treatment and reuse of these assets. Likewise, the National Register status also determines whether proposals must be afforded consideration in federal project planning under Section 106, or whether historic properties can qualify as “certified historic structures” eligible to receive the 20 percent Federal Historic Preservation Tax Credit (FHPTC) for the rehabilitation of historic, income-producing buildings. Other tax incentives are often coupled with this credit to revitalize historic neighborhoods, such as the Federal Low-Income Housing Tax Credit and state and local historic preservation tax incentives. Recent studies have documented that these tax incentive programs contribute to economic development and job production, making them a primary tool for revitalizing neighborhoods that were once considered blighted.
The principles outlined below offer useful guidance that can assist communities in their efforts to incorporate historic preservation into planning revitalization efforts. Collaboration among federal, state, and local officials, SHPOs, THPOs, developers, residents, and other stakeholders is essential to successfully implement these principles. To foster such collaboration, this Policy Statement provides a framework that departs from traditional preservation doctrine in order to promote the effective contribution of historic assets
These principles are interpreted below to provide context for stakeholders who may consider applying them to their communities.
I. Historic preservation principles should guide the preservation and reuse of older community assets.
II. Historic preservation should be incorporated in local planning efforts that focus on sustainability and smart growth.
III. Historic preservation should be incorporated into plans prepared by local governments that receive financial and technical assistance to build resilient communities.
IV. Historic property inventories and surveys prepared by digital mapping and other traditional methods are tools that can assist communities seeking federal, state, and local resources for planning and revitalization projects.
V. The flexibility inherent in the National Register criteria should be recognized by state and local governments when considering the significance of resources within distressed communities.
VI. Early consideration of alternatives to avoid or minimize adverse effects of projects involving historic properties is essential to ensure the proper integration of historic properties in community revitalization plans.
VII. Effective citizen engagement that reflects the diversity of the community can assist in identifying historic properties and cultural resources that should be recommended for preservation.
VIII. Indian tribes may have an interest in urban and rural community revitalization projects and the effects they may have on historic properties to which they attach religious and cultural significance.
IX. Tax credits and tax incentives can be used to promote historic preservation projects that preserve local assets.
X. Flexibility in the treatment of some historic buildings in Section 106 reviews can help achieve broader neighborhood preservation goals.
XI. Private resources can contribute to local revitalization efforts and also leverage public funds.
XII. Flexible and programmatic solutions developed as part of Section 106 reviews can expedite historic preservation reviews as well as more effectively address the chronic demolition of historic properties.
XIII. Creative mitigation that balances historic preservation values and program goals should be explored by stakeholders and incorporated into Section 106 outcomes.
Responding to the widespread destruction of historic resources during the urban renewal programs of the 1950s and 1960s, the NHPA was established to ensure local community revitalization and economic development projects were responsive to historic preservation principles. Unfortunately, 50 years later, the provisions of the NHPA requiring consideration of historic properties in project planning are not applied consistently by federal, state, and local governments. This is particularly the case when federal funds are allocated to local communities to address substantial amounts of vacant and abandoned buildings. Historic properties should be considered and evaluated as community assets because of their ability to endure cyclical changes and continue to provide shelter and economic development to residents of all incomes. Their treatment should be informed by an analysis of alternatives, including stabilization, rehabilitation, new infill construction, and, in certain cases, demolition. When integrated into project planning as prescribed by Section 106 of the NHPA, historic preservation tools can be beneficial to achieving local revitalization goals. Rather than being viewed as part of the problem, historic properties can be adapted and reused as a viable alternative. They should be given due consideration by federal, state, and local officials when developing comprehensive and small area plans and neighborhood vision frameworks. Although historic preservation is often ignored by stakeholders who express a desire for new construction, decades of successful historic preservation projects affirm that renewed historic assets can meet community expectations for modern uses while maintaining the character that traditionally defined the area.
The core principles in sustainability and smart growth have been embraced by urban and rural communities nationwide during the past decades. Smart growth is a cohesive group of planning principles that are focused on creating sustainable development patterns. Sustainable communities are focused on conserving and improving existing resources, including making historic assets such as buildings, neighborhoods, and communities greener, stronger, and more livable. Both smart growth and sustainability can foster historic preservation, emphasizing the value in preserving and reusing historic properties that illustrate the character of communities rather than filling up landfills with building materials. Successful historic preservation techniques often bring together both historic properties and compatible new construction to create a dynamic and attractive environment. Preserving historic properties not only retains streetscapes and original settings but also can create a focal point for a community to embrace its history, culture, and sense of place. This can be a major contribution to achieving community revitalization goals to stabilize distressed communities and to promote long-term viability.
In the aftermath of natural disasters, climate change events, and unanticipated emergencies, disaster recovery projects are often designed to revitalize and rebuild resilient communities. Communities also adopt practices before disasters strike to make them more resilient. Resilient communities are better able to recover from disasters and disruptions in a sustainable way and maintain their vitality and viability. Achieving community resiliency goals consistent with local historic preservation priorities requires aligning federal funding with local rebuilding visions, cutting red tape for obtaining assistance, developing region-wide plans for rebuilding, and ensuring that communities are rebuilt to better withstand future threats. Maintaining, rehabilitating, and reusing existing historic buildings can contribute to stabilizing and revitalizing neighborhoods. Community recovery and revitalization plans should be specific in their use and treatment of historic properties and coordinated with plans for new construction and infrastructure. Recognizing that historic preservation strategies are compatible with resilient community goals will enable planners to create housing choices, foster a sense of place, generate jobs, maintain walkable neighborhoods, and preserve open spaces. All these factors are critical to promoting resilient communities that include integration of historic properties.
Historic property inventories and surveys developed by qualified professionals documenting historic properties within a local community are frequently incomplete and dated or too often completely lacking. The absence of this basic information can result in the inadvertent loss of historic properties as well as delays in project planning and implementation. Without the historical context explaining the evolution of neighborhoods and the significance of existing building stock, decision making is uninformed. In contrast, communities that have current, up to date historic property inventories and surveys which provide historic context; identify architecture, archaeological sites, and cultural resources; and define historic districts are able to assist local officials and developers in preparing effective revitalization strategies. When local governments use this tool in advance of applying for grants and loans, they can identify areas that should be given special attention in project planning and gather input from residents on what is important to them about their neighborhoods. Also, inventory and survey information allows local officials the flexibility of de-listing National Register properties when the integrity is lost due to neglect and extensive amounts of abandonment of historic properties.
The National Register is broad enough to recognize and include under-represented communities and find creative approaches to recognize the history and culture of areas and resources preserved against tremendous odds. It should be recognized that as communities have aged and assets have been neglected, particularly in distressed communities, physical integrity may suffer. However, such resources may still possess cultural and social significance that may qualify them nonetheless for their associative value to the community and as embodiment of broad patterns of history. Where local communities have prepared lists of local landmarks unique to the city, those resources may very well meet the National Register criteria for eligibility on the local level. Section 106 reviews can factor in this information when considering alternatives and mitigation. Federal and state agencies that prepare National Environmental Policy Act documents should already be including local heritage and culture under chapters on Social and Economic Conditions and Cultural Resources.
Effective utilization of historic properties to support community revitalization goals requires that preservation be an integral part of local planning from the outset. Strategic efforts to stabilize local neighborhoods in communities experiencing unprecedented amounts of vacancies and abandonment and substantial population loss should consider alternatives that can have a positive impact. Comprehensive neighborhood plans, small area plans, and more targeted vision frameworks should disclose the criteria and processes local officials use to determine specific treatment for buildings and sites. SHPOs can also provide technical assistance when resources are available. Likewise, communities with CLGs that work closely with SHPOs can participate in local administrative reviews and provide advice regarding how historic properties may be affected by community revitalization plans. SHPOs and CLGs can work with the local community development agencies and land banks to determine how they can facilitate building preservation, rehabilitation, and revitalization, as well as plans proposed for substantial demolitions in target areas or on a community-wide basis. Essential to effective early planning is the engagement of the local community that is affected by the proposed action.
The consultation process carried out under Section 106 is designed to elicit effective and informed citizen engagement. Public participation will help to identify places and historic properties important to the community early in the consultation process and foster creative solutions that accommodate the community's heritage with revitalization. Special attention should be given to including diverse residents in communities that have been overlooked in prior identification efforts. Places associated with under-represented communities are not broadly listed on the National Register, so it is important that local officials make citizen engagement a priority when evaluating properties for National Register eligibility in the Section 106 process or developing surveys and inventories. SHPOs can often assist local officials in providing historic context statements for such properties and existing information on community resources. Involving local academic institutions, civic organizations, professional associations, neighborhood associations, and tribal representatives in the work of local preservation commissions and architectural review boards can help ensure that the views of all segments of the community inform the identification and evaluation of historic properties. Citizen engagement also is critical in the analysis of project alternatives to deal with adverse effects of revitalization projects on historic properties. Many of the outcomes from Section 106 reviews are shaped by recommendations from citizens who participate as consulting parties in the process. Federal and local officials provide guidance and technical assistance to facilitate citizen engagement in completing inventories and surveys, developing local project plans, and participating in the required project review processes.
It is important to involve Indian tribes in Section 106 reviews, particularly in the identification and evaluation of historic properties and assessment of effects. Since THPOs and Indian tribes are required to be invited to participate in Section 106 as consulting parties, federal and local officials should become familiar with those Indian tribes that have ancestral and historic associations with their communities. It is important that planners look beyond archaeologists in assessing the significance of sites, as these resources often have traditional cultural or religious value to Native Americans. Indian tribes can also contribute to local sustainability efforts based on their ecological and environmental knowledge of geographic areas to which they have traditional ties. Involving
Recent research conducted on the impacts of using Federal Historic Preservation Tax Credits (FHPTC) have revealed that investments in historic rehabilitation have greater positive impact on employment, state and local taxes, and the financial strength of the state than new construction. The use of FHPTCs, Low Income Housing Tax Credits, state historic tax credits, and local historic tax credits can often be combined to provide neighborhoods with financial, social, and economic benefits. Local governments should consider how these incentives can be used to fund not only major projects but also small and mid-size neighborhood projects that involve local historic properties. SHPOs are uniquely situated to leverage FHPTC projects, having worked closely with the National Park Service and developers on previous projects. Further, local officials can collaborate with federal regional and field offices, land banks, SHPOs, and local real estate agents to identify vacant and abandoned buildings that are candidates for rehabilitation. By focusing on stabilizing anchor buildings in a neighborhood, local governments can protect these sites and make them available to developers who intend to revitalize target areas with major projects such as those for affordable housing and transit-oriented development.
Sometimes historic neighborhoods confront significant abandonment and serious deterioration of building stock, such that rehabilitation and reuse becomes an overwhelming challenge. Participants in Section 106 consultations should be receptive to considering different treatment measures, including new infill construction meeting the Secretary's Standards, substitute materials, and strategic demolition, when there is concurrence that such an approach is the best approach to achieving broader community revitalization and preservation goals. It is strongly encouraged that federal agencies and applicants utilize historic preservation professionals to help determine when and how it may be appropriate to apply flexibility in the treatment of individual buildings.
Private resources are instrumental in ensuring most community revitalization efforts are successful and transformative. Examples of federal grant and loan programs used in conjunction with private resources for local revitalization efforts include the Department of Transportation's TIGER Program and the Environmental Protection Agency's Brownfield Grants. These programs require local communities to provide matching funds, which are often solicited from the private sector. Local institutions such as universities, hospitals, foundations, banks, land banks, and local businesses are frequently the source for matching funds. In addition, they often partner with developers on multi-use projects that benefit the community as a whole. Banking institutions are able to get credit under the federal Community Reinvestment Act (CRA) program when they contribute to local revitalization efforts. A bank's CRA performance record is taken into account when evaluating its overall performance. Therefore, project proponents and local officials should reach out to local banking institutions to discuss strategies regarding loans for commercial and residential community revitalization projects. When using private resources to assist with revitalization projects, local officials should inform the funding entity of the importance of the local historic preservation principles to the community to ensure they are not inadvertently compromised.
Community revitalization projects with federal involvement require compliance with Section 106 and other federal environmental laws. Frequently, programmatic solutions that address the broad effects resulting from the implementation of multiple projects can expedite compliance with regulatory requirements, improving the efficiency of project delivery. Section 106 Programmatic Agreements, which are quite varied, are intended to manage multiple projects that result in similar types of effects, can respond to local conditions, foster community preservation goals, and expedite project reviews. Such agreements often clarify that plans and specifications developed for local community revitalization projects should adhere to the recommended approaches in the Secretary's Standards, when feasible, and qualify for simplified reviews. When communities cannot consistently adhere to the Secretary's Standards, they should consider developing project plans that are based largely on the Secretary's Standards but provide greater flexibility. The public interest in preservation should guide planning, such as focusing reviews on exterior features and limiting reviews of interior spaces to those areas open to the public. Planning for larger scale revitalization projects should occur in advance of submitting applications for federal monies, and allow local officials to target any grants received into grants and loans to areas that can be stabilized. Given the often changing financial market and the passage of time in many communities where revitalization activities are limited, securing and stabilizing buildings may be a useful interim measure. It can avoid the loss of substantial numbers of historic properties in areas that may ultimately rebound.
“Creative mitigation” is a concept that allows federal agencies, in consultation with stakeholders, to use non-traditional approaches to compensate for adverse effects that cannot be avoided or offset by using standard mitigation techniques. In Section 106 reviews, standard mitigation measures are customarily directed at the affected historic property and may include recordation, data recovery, or curation. Sometimes the public benefit of using these standard measures is minimal, and allocation of funds for other preservation activities would be prudent. Federal agencies, SHPOs, CLGs, and other consulting parties are encouraged to be open to creative mitigation when consulting to resolve adverse effects on historic properties. Any mitigation for the loss of historic properties or materials should both provide public benefit and be commensurate with the extent of loss. The activities proposed in creative mitigation measures also should
Federal, state, and local officials; applicants; residents; and preservationists are encouraged to use the above principles when developing community revitalization plans and coordinating Section 106 reviews. Please visit the ACHP's Web site,
54 U.S.C. 304102
Federal Emergency Management Agency, DHS.
Notice.
The Federal Emergency Management Agency (FEMA) will submit the information collection abstracted below to the Office of Management and Budget for review and clearance in accordance with the requirements of the Paperwork Reduction Act of 1995. The submission will describe the nature of the information collection, the categories of respondents, the estimated burden (
Comments must be submitted on or before December 16, 2016.
Submit written comments on the proposed information collection to the Office of Information and Regulatory Affairs, Office of Management and Budget. Comments should be addressed to the Desk Officer for the Department of Homeland Security, Federal Emergency Management Agency, and sent via electronic mail to
Requests for additional information or copies of the information collection should be made to Director, Records Management Division, 500 C Street SW., Washington, DC 20472-3100, or email address
This information collection previously published in the
Federal Emergency Management Agency, DHS.
Notice.
The Federal Emergency Management Agency (FEMA) will submit the information collection abstracted below to the Office of Management and Budget for review and clearance in accordance with the requirements of the Paperwork Reduction Act of 1995. The submission will describe the nature of the information collection, the categories of respondents, the estimated burden (
Comments must be submitted on or before December 16, 2016.
Submit written comments on the proposed information collection to the Office of Information and Regulatory Affairs, Office of Management and Budget. Comments should be addressed to the Desk Officer for the Department of Homeland Security, Federal Emergency Management Agency, and sent via electronic mail to
Requests for additional information or copies of the information collection should be made to Director, Records Management Division, 500 C Street SW., Washington, DC 20472-3100, or email address
This information collection previously published in the
Department of Homeland Security.
Committee Management; Notice of partially Closed Federal Advisory Committee Meeting.
The President's National Security Telecommunications Advisory Committee (NSTAC) will meet on Wednesday, December 7, 2016, in Washington, DC The meeting will be partially closed to the public.
The NSTAC will meet on Wednesday, December 7, 2016, from 9:00 a.m. to 3:20 p.m. Eastern Standard Time (EST). Please note that the meeting may close early if the committee has completed its business.
The December 2016 NSTAC Meeting's open session will be held at the Eisenhower Executive Office Building, Washington, DC. Due to limited seating, requests to attend in person will be on a first-come basis and the public portion of the meeting will be streamed via webcast at
Members of the public are invited to provide comment on the issues to be considered by the committee as listed in the
Comments may be submitted by one of the following methods:
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A public comment period will be held during the meeting from 2:50 p.m. to 3:20 p.m. Speakers who wish to participate in the public comment period must register in advance and can do so by emailing
Helen Jackson, NSTAC Designated Federal Officer, Department of Homeland Security, (703) 235-5321 (telephone) or
Notice of this meeting is given under the
The committee will also meet in a closed session to receive a classified briefing regarding cybersecurity threats and discuss future studies based on the Government's NS/EP priorities and perceived vulnerabilities.
The first of these agenda items, the classified briefing, will provide members with a cybersecurity threat briefing on threats to critical infrastructure. Disclosure of these threats would provide criminals who seek to compromise commercial and Government networks with information on potential vulnerabilities and mitigation techniques, weakening the Nation's cybersecurity posture. This briefing will be classified at the top secret/sensitive compartmented information level, thereby exempting disclosure of the content by statute. Therefore, this portion of the meeting is required to be closed pursuant to 5 U.S.C. 552b(c)(1)(A) & (B).
The second agenda item, the discussion of potential NSTAC study topics, will address areas of critical cybersecurity vulnerabilities and priorities for Government. Government officials will share data with NSTAC members on initiatives, assessments, and future security requirements across public and private sector networks. The information will include specific vulnerabilities within cyberspace that affect the United States' ICT infrastructures and proposed mitigation strategies. Disclosure of this information to the public would provide criminals with an incentive to focus on these vulnerabilities to increase attacks on the Nation's critical infrastructure and communications networks. As disclosure of this portion of the meeting is likely to significantly frustrate implementation of proposed DHS actions, it is required to be closed pursuant to 5 U.S.C. 552b(c)(9)(B).
The Office of Partnership and Engagement, DHS.
Notice of partially closed Federal Advisory Committee meeting.
The Homeland Security Advisory Council (“Council”) will meet in person on Thursday, December 1, 2016. Members of the public may participate in person. The meeting will be partially closed to the public.
The Council will meet Thursday, December 1, 2016, from 10:15 a.m. to 4:30 p.m. EST. The meeting will be open to the public from 1:30 p.m. to 3:30 p.m. EST. Please note the meeting may close early if the Council has completed its business. The meeting will be closed to the public from 10:15 a.m. to 12:30 p.m. and 3:45 p.m. to 4:30 p.m. EST.
The meeting will be held at the Woodrow Wilson International Center for Scholars (“Wilson Center”), located at 1300 Pennsylvania Avenue NW., Washington, DC 20004. All visitors will be processed through the lobby of the Wilson Center. Written public comments prior to the meeting must be received by 5:00 p.m. EST on Monday, November 28, 2016, and must be identified by Docket No. DHS-2016-0056. Written public comments after the meeting must be identified by Docket No. DHS-2016-0056 and may be submitted by
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Mike Miron at
Notice of this meeting is given under Section 10(a) of the Federal Advisory Committee Act (FACA), Public Law 92-463 (5 U.S.C. Appendix), which requires each FACA committee meeting to be open to the public.
The Council provides organizationally independent, strategic, timely, specific, actionable advice, and recommendations to the Secretary of the Department of Homeland Security on matters related to homeland security. The Council is comprised of leaders of local law enforcement, first responders, federal, state, and local government, the private sector, and academia.
The Council will meet in an open session between 1:30 p.m. to 3:30 p.m. EST. The Council may review and deliberate on the Privatized Immigration Detention Facilities Subcommittee's interim report or final recommendations, and receive an update from the Countering Violent Extremism Subcommittee.
The Council will meet in a closed session from 10:15 a.m. to 12:30 p.m. EST, and from 3:45 p.m. to 4:30 p.m. EST, to receive sensitive operational information from senior officials on current counterterrorism threats, the Presidential transition, the Transportation and Security Administration, and cybersecurity.
The Council will receive closed session briefings from senior officials. These briefings will concern matters sensitive to homeland security within the meaning of 5 U.S.C. 552b(c)(7)(E) and 552b(c)(9)(B). The Council will receive operational counterterrorism updates on the current threat environment and security measures associated with countering such threats,
The session is closed under 5 U.S.C. 552b(c)(7)(E) because disclosure of that information could reveal investigative techniques and procedures not generally available to the public, allowing terrorists and those with interests against the United States to circumvent the law and thwart the Department's strategic initiatives. In addition, the session is closed pursuant to 5 U.S.C. 552b(c)(9)(B) because disclosure of these techniques and procedures could frustrate the successful implementation of protective measures designed to keep our country safe.
Office of the Assistant Secretary for Policy Development and Research, HUD.
Notice.
On June 16, 2016, HUD sought comment on applying Small Area Fair Market Rents (Small Area FMRs) to certain metropolitan areas for administration of the Housing Choice Voucher (HCV) program based on certain selection criteria and selection values. Found elsewhere in this issue of the
For information about this rule, contact Peter B. Kahn, Director, Economic and Market Analysis Division, Office of Economic Affairs, Office of Policy Development and Research, U.S. Department of Housing and Urban Development, 451 7th Street SW., Washington, DC 20410, telephone (202) 402-2409; email:
On June 2, 2015, at 80 FR 31332, HUD published an advance notice of final rulemaking (ANPR) entitled “Establishing a More Effective Fair Market Rent (FMR) System; Using Small Area Fair Market Rents (Small Area FMRs) in Housing Choice Voucher Program Instead of the Current 50th Percentile FMRs.” In this ANPR, HUD announced its intention to amend HUD's FMR regulations applicable to the HCV program and sought public comment on the use of certain criteria for setting Small Area FMRs for the HCV program within certain metropolitan areas.
On June 16, 2016, at 81 FR 39218, HUD published a proposed rule that would require the use of Small Area FMRs in place of the 50th percentile rent to address high levels of voucher concentration. The proposed rule addressed the issues and suggestions raised by public commenters on the ANPR, and in response to public comments proposed new criteria for setting Small Area FMRs for the HCV program.
The proposed regulation provided, in 24 CFR 888.113(c), to set Small Area FMRs for metropolitan areas where at least 2,500 HCVs are under lease; at least 20 percent of the standard quality rental stock, within the metropolitan area, is in small areas (that is ZIP codes) where the Small Area FMR is more than 110 percent of the metropolitan FMR; and the measure of the percentage of voucher holders living in concentrated low-income areas relative to all renters within these areas over the entire metropolitan area exceeds 155 percent (or 1.55).
The proposed regulation also provided, in 24 CFR 888.113(c)(2), that “concentrated low-income areas” means those census tracts in the metropolitan FMR area with a poverty rate of 25 percent or more; or any tract in the metropolitan FMR area where more than 50 percent of the households earn incomes at less than 60 percent of the area median income (AMI) and are designated as Qualified Census Tracts in accordance with section 42 of the Internal Revenue Code (26 U.S.C. 42). Lastly, the proposed regulation provided, in 24 CFR 888.113(c)(3), that if a metropolitan area meets the criteria for application of Small Area FMRs to the area, all PHAs administering HCV programs in that area will be required to use Small Area FMRs.
In addition to setting forth new proposed criteria, HUD specifically requested comment on whether HUD should codify in regulatory text the selection parameters for Small Area FMRs or if they should be incorporated into each annual FMR notice, subject to public comment, to provide HUD, PHAs, and other stakeholders with flexibility to offer changes to the selection parameters. HUD also asked for comments on the criteria that HUD selected for determining which metropolitan areas should be impacted by the shift to a Small Area FMR instead of the current 50th percentile policy.
The final rule, found elsewhere in the
In response to comments, HUD also adds two new selection criteria to those provided in the proposed rule. First, HUD adds the vacancy rate of an area as a criterion to the selection parameters for Small Area FMRs and excludes metropolitan areas with a certain ACS vacancy rate from being designated a Small Area FMR area. Second, HUD adds a threshold for the voucher concentration ratio to better target communities where voucher concentration is most severe. Consequently, in addition to the voucher concentration ratio included in the proposed rule, the final rule also requires the numerator of this measure, the concentration of voucher holders within concentrated low income areas, to meet a minimum standard level.
Through this notice, HUD is setting the selection values to determine the first-set of metropolitan FMR areas subject to Small Area FMRs for use in the administration of tenant-based assistance under the HCV program. Metropolitan FMR areas that meet the following requirement will be subject to Small Area FMRs consistent with 24 CFR 888.113(c):
(i) There are at least 2,500 HCV under lease;
(ii) At least 20 percent of the standard quality rental stock, within the metropolitan FMR area is in small areas (ZIP codes) where the Small Area FMR is more than 110 percent of the metropolitan FMR;
(iii) The percentage of voucher families living in concentrated low income areas relative to all renters within the area must be at least 25 percent;
(iv) The measure of the percentage of voucher holders living in concentrated low income areas relative to all renters within these areas over the entire metropolitan area exceeds 155 percent (or 1.55); and
(v) The vacancy rate for the metropolitan area is higher than 4 percent. The vacancy rate is calculated using data from the 1-year American Community Survey (ACS) tabulations, the vacancy rate is the number of Vacant For Rent Units divided by the sum of the number of Vacant For Rent Units, the number of Renter Occupied Units, and the number of Rented, not occupied units. The vacancy rate will be calculated from the 3 most current ACS 1 year datasets available and average the 3 values.
The metropolitan FMR Areas that meet these requirements are as follows:
30-Day notice.
To comply with the Paperwork Reduction Act of 1995 (PRA), the Bureau of Safety and Environmental Enforcement (BSEE) is notifying the public that we have submitted to OMB an information collection request (ICR) to renew approval of the paperwork requirements in the regulations under Subpart P,
You must submit comments by December 16, 2016.
Submit comments by either fax (202) 395-5806 or email (
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Kelly Odom, Regulations and Standards Branch, (703) 787-1775, to request additional information about this ICR. To see a copy of the entire ICR submitted to OMB, go to
In addition to the general rulemaking authority of the OCSLA at 43 U.S.C. 1334, section 301(a) of the Federal Oil and Gas Royalty Management Act (FOGRMA), 30 U.S.C. 1751(a), grants authority to the Secretary to prescribe such rules and regulations as are reasonably necessary to carry out FOGRMA's provisions. While the majority of FOGRMA is directed to royalty collection and enforcement, some provisions apply to offshore operations. For example, section 108 of FOGRMA, 30 U.S.C. 1718, grants the Secretary broad authority to inspect lease sites for the purpose of determining whether there is compliance with the mineral leasing laws. Section 109(c)(2) and (d)(1), 30 U.S.C. 1719(c)(2) and (d)(1), impose substantial civil penalties for failure to permit lawful inspections and for knowing or willful preparation or submission of false, inaccurate, or misleading reports, records, or other information. Because the Secretary has delegated some of the authority under FOGRMA to BSEE, 30 U.S.C. 1751 is included as additional authority for these requirements.
Regulations implementing these responsibilities are under 30 CFR part 250. Some responses are mandatory and some are required to obtain or retain a benefit. No questions of a sensitive nature are asked. BSEE will protect proprietary information according to the Freedom of Information Act (5 U.S.C. 552) and DOI's implementing regulations (43 CFR 2); 30 CFR 250.197,
BSEE uses the information collected under subpart P to:
• Ascertain that a discovered sulfur deposit can be classified as capable of production in paying quantities.
• ensure accurate and complete measurement of production to determine the amount of sulfur royalty payments due the United States; and that the sale locations are secure, production has been measured accurately, and appropriate follow-up actions are initiated.
• ensure the adequacy and safety of firefighting systems; the drilling unit is fit for the intended purpose; and the adequacy of casing for anticipated conditions.
• review drilling, well-completion, well-workover diagrams and procedures, as well as production operation procedures to ensure the safety of the proposed sulfur drilling, well-completion, well-workover and proposed production operations.
• monitor environmental data during sulfur operations in offshore areas where such data are not already available to provide a valuable source of information to evaluate the performance of drilling rigs under various weather and ocean conditions. This information is necessary to make reasonable determinations regarding safety of operations and environmental protection.
To comply with the public consultation process, on June 3, 2016, we published a
United States International Trade Commission.
Schedule for 2017 report and opportunity to submit information.
The Commission has prepared and published annual reports in this series under investigation No. 332-345, Recent Trends in U.S. Services Trade, since 1996. The 2017 report, which the Commission plans to publish in May 2017, will provide aggregate data on cross-border trade in services for the period ending in 2015, and transactions by affiliates based outside the country of their parent firm for the period ending in 2014. The report's analysis will focus on professional services (including accounting and auditing, architecture and engineering, legal services, and business management and consulting).The Commission is inviting interested members of the public to furnish information and views in connection with the 2017 report.
December 16, 2016: Deadline for filing written submissions.
May 19, 2017: Anticipated date for publishing the report.
All Commission offices are located in the United States International Trade Commission Building, 500 E St. SW., Washington, DC. All written submissions should be addressed to the Secretary, United States International Trade Commission, 500 E St. SW., Washington, DC 20436. The public record for this investigation may be viewed on the Commission's electronic docket information system (EDIS) at
Project Leader Art Chambers (202-205-2766 or
Background: The 2017 annual services trade report will provide aggregate data on cross-border trade and affiliate transactions in services, and more specific data and information on trade in professional services (accounting and auditing, architecture and engineering, legal services, and business and management consulting). Under Commission investigation No. 332-345, the Commission publishes two annual reports, one on services trade (Recent Trends in U.S. Services Trade), and a second on merchandise trade (Shifts in U.S. Merchandise Trade). The Commission's 2016 annual report in the series of reports on Recent Trends in U.S. Services Trade is now available online at
The initial notice of institution of this investigation was published in the
The Commission intends to prepare only a public report in this investigation. The report that the Commission makes available to the public will not contain confidential business information. However, all information, including confidential business information, submitted in this investigation may be disclosed to and used: (i) By the Commission, its employees and Offices, and contract personnel (a) for developing or maintaining the records of this or a related proceeding, or (b) in internal investigations, audits, reviews, and evaluations relating to the programs, personnel, and operations of the Commission including under 5 U.S.C. Appendix 3; or (ii) by U.S. government employees and contract personnel solely for cybersecurity purposes. The Commission will not otherwise disclose any confidential business information in a manner that would reveal the operations of the firm supplying the information.
By order of the Commission.
On the basis of the record
The Commission, pursuant to sections 705(b) and 735(b) of the Act (19 U.S.C. 1671d(b) and 19 U.S.C. 1673d(b)), instituted these investigations effective September 30, 2015, following receipt of a petition filed with the Commission and Commerce by Bristol Metals, LLC, Bristol, Tennessee; Felker Brothers Corp., Marshfield, Wisconsin; Marcegaglia USA, Munhall, Pennsylvania; and Outokumpu Stainless Pipe, Inc., Wildwood, Florida. The final phase of the investigations was scheduled by the Commission following notification of preliminary determinations by Commerce that imports of welded stainless steel pressure pipe from India were subsidized within the meaning of section 703(b) of the Act (19 U.S.C. 1671b(b)) and dumped within the meaning of 733(b) of the Act (19 U.S.C. 1673b(b)). Notice of the scheduling of the final phase of the Commission's investigations and of a public hearing to be held in connection therewith was given by posting copies of the notice in the Office of the Secretary, U.S. International Trade Commission, Washington, DC, and by publishing the notice in the
The Commission made these determinations pursuant to sections 705(b) and 735(b) of the Act (19 U.S.C. 1671d(b) and 19 U.S.C. 1673d(b)). It completed and filed its determinations in these investigations on November 9, 2016. The views of the Commission are contained in USITC Publication 4644 (November 2016), entitled
By order of the Commission.
Bureau of Alcohol, Tobacco, Firearms, and Explosives (ATF); Department of Justice.
Notice of list of explosive materials.
Pursuant to 18 U.S.C. 841(d) and 27 CFR 555.23, the Department must publish and revise at least annually in the
The list becomes effective November 16, 2016.
William E. Frye Jr., Chief, Explosives Industry Programs Branch; Firearms and Explosives Industry Division; Bureau of Alcohol, Tobacco, Firearms, and Explosives; United States Department of Justice; 99 New York Avenue NE., Washington, DC 20226; 202 648-7120.
The list includes all mixtures containing any of the materials on the list. Materials constituting blasting agents are marked by an asterisk. While the list is comprehensive, it is not all-inclusive. The fact that an explosive material is not on the list does not mean that it is not within the coverage of the law if it otherwise meets the statutory definitions in 18 U.S.C. 841. Explosive materials are listed alphabetically by their common names followed, where applicable, by chemical names and synonyms in brackets.
The Department amends the term, “Xanthamonas hydrophilic colloid explosive mixture” to “Xanthomonas hydrophilic colloid explosive mixture” to more accurately reflect reference to this material in the list of explosive materials. The term “Xanthamonas” was included as part of a 1967 patent of a gelled explosive containing a Xanthomonas hydrophilic colloid and was erroneously used as synonymous with the broader class of Xanthomonas hydrophilic colloid explosive mixtures. Further, the Department removes the term “Special fireworks” that was previously used to describe those fireworks currently classified as display fireworks. The definition of “Special fireworks” was removed and the definition of “Display fireworks” was added in its place to Part 555 (formerly Part 55) in a final rule (63 FR, 45001, August 24, 1998). However, “Special fireworks” was not removed from the list of explosive materials at that time. These revisions are being made for clarity and consistency within all explosives laws and regulations. This list supersedes the List of Explosive Materials dated October 23, 2015 (Docket No. 2015R-23, 80 FR 64446).
Pursuant to 18 U.S.C. 841(d) and 27 CFR 555.23, I hereby designate the following as explosive materials covered under 18 U.S.C. 841(c):
Acetylides of heavy metals.
Aluminum containing polymeric propellant.
Aluminum ophorite explosive.
Amatex.
Amatol.
Ammonal.
Ammonium nitrate explosive mixtures (cap sensitive).
*Ammonium nitrate explosive mixtures (non-cap sensitive).
Ammonium perchlorate having particle size less than 15 microns.
Ammonium perchlorate explosive mixtures (excluding ammonium perchlorate composite
propellant (APCP)).
Ammonium picrate [picrate of ammonia, Explosive D].
Ammonium salt lattice with isomorphously substituted inorganic salts.
*ANFO [ammonium nitrate-fuel oil].
Aromatic nitro-compound explosive mixtures.
Azide explosives.
Baranol.
Baratol.
BEAF [1, 2-bis (2, 2-difluoro-2-nitroacetoxyethane)].
Black powder.
Black powder based explosive mixtures.
Black powder substitutes.
*Blasting agents, nitro-carbo-nitrates, including non-cap sensitive slurry and water gel
explosives.
Blasting caps.
Blasting gelatin.
Blasting powder.
BTNEC [bis (trinitroethyl) carbonate].
BTNEN [bis (trinitroethyl) nitramine].
BTTN [1,2,4 butanetriol trinitrate].
Bulk salutes.
Butyl tetryl.
Calcium nitrate explosive mixture.
Cellulose hexanitrate explosive mixture.
Chlorate explosive mixtures.
Composition A and variations.
Composition B and variations.
Composition C and variations.
Copper acetylide.
Cyanuric triazide.
Cyclonite [RDX].
Cyclotetramethylenetetranitramine [HMX].
Cyclotol.
Cyclotrimethylenetrinitramine [RDX].
DATB [diaminotrinitrobenzene].
DDNP [diazodinitrophenol].
DEGDN [diethyleneglycol dinitrate].
Detonating cord.
Detonators.
Dimethylol dimethyl methane dinitrate composition.
Dinitroethyleneurea.
Dinitroglycerine [glycerol dinitrate].
Dinitrophenol.
Dinitrophenolates.
Dinitrophenyl hydrazine.
Dinitroresorcinol.
Dinitrotoluene-sodium nitrate explosive mixtures.
DIPAM [dipicramide; diaminohexanitrobiphenyl].
Dipicryl sulfone.
Dipicrylamine.
Display fireworks.
DNPA [2,2-dinitropropyl acrylate].
DNPD [dinitropentano nitrile].
Dynamite.
EDDN [ethylene diamine dinitrate].
EDNA [ethylenedinitramine].
Ednatol.
EDNP [ethyl 4,4-dinitropentanoate].
EGDN [ethylene glycol dinitrate].
Erythritol tetranitrate explosives.
Esters of nitro-substituted alcohols.
Ethyl-tetryl.
Explosive conitrates.
Explosive gelatins.
Explosive liquids.
Explosive mixtures containing oxygen-releasing inorganic salts and hydrocarbons.
Explosive mixtures containing oxygen-releasing inorganic salts and nitro bodies.
Explosive mixtures containing oxygen-releasing inorganic salts and water insoluble fuels.
Explosive mixtures containing oxygen-releasing inorganic salts and water soluble fuels.
Explosive mixtures containing sensitized nitromethane.
Explosive mixtures containing tetranitromethane (nitroform).
Explosive nitro compounds of aromatic hydrocarbons.
Explosive organic nitrate mixtures.
Explosive powders.
Flash powder.
Fulminate of mercury.
Fulminate of silver.
Fulminating gold.
Fulminating mercury.
Fulminating platinum.
Fulminating silver.
Gelatinized nitrocellulose.
Gem-dinitro aliphatic explosive mixtures.
Guanyl nitrosamino guanyl tetrazene.
Guanyl nitrosamino guanylidene hydrazine.
Guncotton.
Heavy metal azides.
Hexanite.
Hexanitrodiphenylamine.
Hexanitrostilbene.
Hexogen [RDX].
Hexogene or octogene and a nitrated N-methylaniline.
Hexolites.
HMTD [hexamethylenetriperoxidediamine].
HMX [cyclo-1,3,5,7-tetramethylene 2,4,6,8-tetranitramine; Octogen].
Hydrazinium nitrate/hydrazine/aluminum explosive system.
Hydrazoic acid.
Igniter cord.
Igniters.
Initiating tube systems.
KDNBF [potassium dinitrobenzo-furoxane].
Lead azide.
Lead mannite.
Lead mononitroresorcinate.
Lead picrate.
Lead salts, explosive.
Lead styphnate [styphnate of lead, lead trinitroresorcinate].
Liquid nitrated polyol and trimethylolethane.
Liquid oxygen explosives.
Magnesium ophorite explosives.
Mannitol hexanitrate.
MDNP [methyl 4,4-dinitropentanoate].
MEAN [monoethanolamine nitrate].
Mercuric fulminate.
Mercury oxalate.
Mercury tartrate.
Metriol trinitrate.
Minol-2 [40% TNT, 40% ammonium nitrate, 20% aluminum].
MMAN [monomethylamine nitrate]; methylamine nitrate.
Mononitrotoluene-nitroglycerin mixture.
Monopropellants.
NIBTN [nitroisobutametriol trinitrate].
Nitrate explosive mixtures.
Nitrate sensitized with gelled nitroparaffin.
Nitrated carbohydrate explosive.
Nitrated glucoside explosive.
Nitrated polyhydric alcohol explosives.
Nitric acid and a nitro aromatic compound explosive.
Nitric acid and carboxylic fuel explosive.
Nitric acid explosive mixtures.
Nitro aromatic explosive mixtures.
Nitro compounds of furane explosive mixtures.
Nitrocellulose explosive.
Nitroderivative of urea explosive mixture.
Nitrogelatin explosive.
Nitrogen trichloride.
Nitrogen tri-iodide.
Nitroglycerine [NG, RNG, nitro, glyceryl trinitrate, trinitroglycerine].
Nitroglycide.
Nitroglycol [ethylene glycol dinitrate, EGDN].
Nitroguanidine explosives.
Nitronium perchlorate propellant mixtures.
Nitroparaffins Explosive Grade and ammonium nitrate mixtures.
Nitrostarch.
Nitro-substituted carboxylic acids.
Nitrourea.
Octogen [HMX].
Octol [75 percent HMX, 25 percent TNT].
Organic amine nitrates.
Organic nitramines.
PBX [plastic bonded explosives].
Pellet powder.
Penthrinite composition.
Pentolite.
Perchlorate explosive mixtures.
Peroxide based explosive mixtures.
PETN [nitropentaerythrite, pentaerythrite tetranitrate, pentaerythritol tetranitrate].
Picramic acid and its salts.
Picramide.
Picrate explosives.
Picrate of potassium explosive mixtures.
Picratol.
Picric acid (manufactured as an explosive).
Picryl chloride.
Picryl fluoride.
PLX [95% nitromethane, 5% ethylenediamine].
Polynitro aliphatic compounds.
Polyolpolynitrate-nitrocellulose explosive gels.
Potassium chlorate and lead sulfocyanate explosive.
Potassium nitrate explosive mixtures.
Potassium nitroaminotetrazole.
Pyrotechnic compositions.
Pyrotechnic fuses.
PYX [2,6-bis(picrylamino)] 3,5-dinitropyridine.
RDX [cyclonite, hexogen, T4, cyclo-1,3,5,-trimethylene-2,4,6,-trinitramine; hexahydro-1,3,5-
trinitro-S-triazine].
Safety fuse.
Salts of organic amino sulfonic acid explosive mixture.
Salutes (bulk).
Silver acetylide.
Silver azide.
Silver fulminate.
Silver oxalate explosive mixtures.
Silver styphnate.
Silver tartrate explosive mixtures.
Silver tetrazene.
Slurried explosive mixtures of water, inorganic oxidizing salt, gelling agent, fuel, and sensitizer (cap sensitive).
Smokeless powder.
Sodatol.
Sodium amatol.
Sodium azide explosive mixture.
Sodium dinitro-ortho-cresolate.
Sodium nitrate explosive mixtures.
Sodium nitrate-potassium nitrate explosive mixture.
Sodium picramate.
Squibs.
Styphnic acid explosives.
Tacot [tetranitro-2,3,5,6-dibenzo-1,3a,4,6a tetrazapentalene].
TATB [triaminotrinitrobenzene].
TATP [triacetonetriperoxide].
TEGDN [triethylene glycol dinitrate].
Tetranitrocarbazole.
Tetrazene [tetracene, tetrazine, 1(5-tetrazolyl)-4-guanyl tetrazene hydrate].
Tetrazole explosives.
Tetryl [2,4,6 tetranitro-N-methylaniline].
Tetrytol.
Thickened inorganic oxidizer salt slurried explosive mixture.
TMETN [trimethylolethane trinitrate].
TNEF [trinitroethyl formal].
TNEOC [trinitroethylorthocarbonate].
TNEOF [trinitroethylorthoformate].
TNT [trinitrotoluene, trotyl, trilite, triton].
Torpex.
Tridite.
Trimethylol ethyl methane trinitrate composition.
Trimethylolthane trinitrate-nitrocellulose.
Trimonite.
Trinitroanisole.
Trinitrobenzene.
Trinitrobenzoic acid.
Trinitrocresol.
Trinitro-meta-cresol.
Trinitronaphthalene.
Trinitrophenetol.
Trinitrophloroglucinol.
Trinitroresorcinol.
Tritonal.
Urea nitrate.
Water-bearing explosives having salts of oxidizing acids and nitrogen bases,
sulfates, or sulfamates (cap sensitive).
Water-in-oil emulsion explosive compositions.
Xanthomonas hydrophilic colloid explosive mixture.
On November 4, 2016, the Department of Justice lodged a proposed consent decree with the United States District Court for the Southern District of Mississippi in the lawsuit entitled
The consent decree would resolve claims under CERCLA § 107(a), 42 U.S.C. 9607(a), for recovery of response costs in connection with the Sonford Products Superfund Site in Flowood, Rankin County, Mississippi (“Site”). The consent decree also contains a covenant under CERCLA § 106, 42 U.S.C. 9606, for damages related to injury to, destruction of, or loss of natural resources at the Site. The Mississippi Commission on Environmental Quality is a co-plaintiff; the Consent Decree would resolve its claims under state law.
The six-acre Site is located in Flowood, east of Jackson, Mississippi. Defendant Sonford Products Corporation operated a chemical processing facility at the Site from 1970 to 1985. It formulated pentachlorophenol (“PCP”) for wood preserving and saw mill operations. On April 18, 1985, approximately 2,000 gallons of PCP spilled from the Sonford Products facility into wetlands on the Site. Since that time, the U.S. Environmental Protection Agency and the Mississippi Department of Natural Resources have been responding to the release or threatened release of PCP and other hazardous substances at the Site. The cost of the response is expected to exceed $27 million.
Defendant Sonford Products Corporation has been dissolved. Defendant Estate of William Troy Burford has no assets other than proceeds from insurance policies issued to Sonford Products. The proposed consent decree would allow for the recovery of insurance proceeds from three insurers. The total value of the settlement is $257,500. Of that amount, the Estate will receive $2,500 plus the reasonable fees and expenses associated with administration of the Estate. The United States will receive 95 percent of the remainder and the State of Mississippi will receive 5 percent.
The publication of this notice opens a period for public comment on the proposed consent decree. Comments should be addressed to the Assistant Attorney General, Environment and Natural Resources Division, and should refer to
During the public comment period, the proposed consent decree may be examined and downloaded at this Justice Department Web site:
Please enclose a check or money order for $7.00 (25 cents per page reproduction cost) payable to the United States Treasury.
The Legal Services Corporation's Board of Directors will meet telephonically on November 22, 2016. The meeting will commence at 2:00 p.m., EST, and will continue until the conclusion of the Committee's agenda. Immediately following the Board of Directors telephonic meeting, the Operations and Regulations Committee will hold a telephonic meeting.
John N. Erlenborn Conference Room, Legal Services Corporation Headquarters, 3333 K Street NW., Washington, DC 20007.
Members of the public who are unable to attend in person but wish to listen to the public proceedings may do so by following the telephone call-in directions provided below.
• Call toll-free number: 1-866-451-4981;
• When prompted, enter the following numeric pass code: 5907707348
• When connected to the call, please immediately “MUTE” your telephone.
Members of the public are asked to keep their telephones muted to
Open.
Operations and Regulations Committee—
Katherine Ward, Executive Assistant to the Vice President & General Counsel, at (202) 295-1500. Questions may be sent by electronic mail to
LSC complies with the Americans with Disabilities Act and Section 504 of the 1973 Rehabilitation Act. Upon request, meeting notices and materials will be made available in alternative formats to accommodate individuals with disabilities. Individuals needing other accommodations due to disability in order to attend the meeting in person or telephonically should contact Katherine Ward, at (202) 295-1500 or
National Science Foundation.
Notice.
Effective with the publication of this Notice in the
To view the updated Standardized Research Performance Progress Report Format to be used for both Interim and Final Performance Progress Reporting, see:
The Research Performance Progress Report (RPPR) directly benefits award recipients by making it easier for them to administer Federal grant and cooperative agreement programs through standardization of the types of information required in performance reports—thereby reducing their administrative effort and costs. The RPPR also will make it easier to compare the outputs, outcomes, etc. of research and research-related programs across the government.
The RPPR resulted from an initiative of the Research Business Models (RBM), an Interagency Working Group of the Social, Behavioral & Economic Research Subcommittee of the Committee on Science (CoS), a committee of the National Science and Technology Council (NSTC). One of the RBM Subcommittee's priority areas is to create greater consistency in the administration of Federal research awards. Given the increasing complexity of interdisciplinary and interagency research, it is important for Federal agencies to manage awards in a similar fashion. The RPPR is to be used by agencies that support research and research-related activities for use in submission of progress reports. It is intended to replace other performance reporting formats currently in use by agencies. The RPPR does not change the performance reporting requirements specified in 2 CFR part 200.
On July 23, 2015 the National Science Foundation (NSF) submitted a request for public comment on an Updated Standardized Research Performance Progress Report Format to be used for Both Interim and Final Performance Progress Reporting in the
On behalf of the RBM, NSF has agreed to continue to serve as the sponsor of the updated version of this Federal-wide performance progress reporting format. The final version of the updated Standardized Research Performance Progress Report Format to be used for both Interim and Final Performance Progress Reporting incorporates the public comments mentioned above, and may be viewed at:
In accordance with the Federal Advisory Committee Act (Pub. L. 92-463, as amended), the National Science Foundation (NSF) announces the following meeting:
Nuclear Regulatory Commission.
Draft test plan; request for comment.
The U.S. Nuclear Regulatory Commission (NRC) is requesting public comment on the draft test plan entitled, “Response of Nuclear Power Plant Instrumentation Cables When Exposed to Fire Conditions—Test Plan,” in order to receive feedback from the widest range of interested parties and to ensure that all information relevant to developing this document is available to the NRC staff. The purpose of this draft test plan is to better understand the fire-induced failure modes of instrumentation cables and evaluate the potential effect those failure modes could have on plant instrumentation circuits (
Submit comments by December 16, 2016. Comments received after this date will be considered if it is practical to do so, but the Commission is able to ensure consideration only for comments received on or before this date.
You may submit comments by any of the following methods (unless this document describes a different method for submitting comments on a specific subject):
• Federal Rulemaking Web site: Go to
• Mail comments to: Cindy Bladey, Office of Administration, Mail Stop: OWFN-12-H08, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001.
For additional direction on obtaining information and submitting comments, see “Obtaining Information and Submitting Comments” in the
Gabriel Taylor, Office of Nuclear Regulatory Research, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001; telephone: 301-415-0781, email:
Please refer to Docket ID NRC-2016-0232 when contacting the NRC about the availability of information for this action. You may obtain publicly-available information related to this action by any of the following methods:
•
•
•
Please include Docket ID NRC-2016-0232 in the subject line of your comment submission.
The NRC cautions you not to include identifying or contact information that you do not want to be publicly disclosed in your comment submission. The NRC posts all comment submissions at
If you are requesting or aggregating comments from other persons for submission to the NRC, then you should inform those persons not to include identifying or contact information that they do not want to be publicly disclosed in their comment submission. Your request should state that the NRC does not routinely edit comment submissions to remove such information before making the comment submissions available to the public or entering the comment into ADAMS.
In 1990, the NRC sponsored a series of tests at Sandia National Laboratories (SNL) to investigate the effects of thermal aging on fire damageability, documented in NUREG/CR-5546, “An Investigation of the Effects of Thermal Aging on the Fire Damageability of Electric Cables” (ADAMS Accession No. ML041270223). An instrumentation cable was tested to determine the failure time and temperature for both aged and unaged cables. During the testing, levels of leakage current, on the order of 15 mA, were observed prior to the onset of catastrophic failure. In 2001, additional testing was performed by the Nuclear Energy Institute and the Electric Power Research Institute. The NRC was invited to observe and participate by sponsoring SNL to evaluate various cables and instrumentation techniques. Six tests included instrumentation cables and those results are documented in NUREG/CR-6776, “Cable Insulation Resistance Measurements Made During Cable Fire Tests” (ADAMS Accession No. ML022600316). Those results indicated pronounced differences observed between the failure of the thermoplastic and thermoset insulated cables. In previous years the NRC has published cable functionality test reports which focused on power and control cables when exposed to fire conditions including: NUREG/CR-7102, “Kerite Analysis in Thermal Environment of FIRE (KATE-Fire): Test Results” (ADAMS Accession No.
The purpose of this draft test plan is to better understand the fire-induced failure modes of instrumentation cables and evaluate the potential effect those failure modes could have on plant instrumentation circuits (
The NRC is requesting public comment in order to receive feedback from the widest range of interested parties and to ensure that all information relevant to developing this document is available to the NRC staff. This document is not intended for interim use. The NRC will review public comments received on the document, incorporate suggested changes as necessary, and make the final test plan available.
For the Nuclear Regulatory Commission.
Postal Regulatory Commission.
Notice.
The Commission is noticing a recent Postal Service filing for the Commission's consideration concerning a negotiated service agreement. This notice informs the public of the filing, invites public comment, and takes other administrative steps.
Submit comments electronically via the Commission's Filing Online system at
David A. Trissell, General Counsel, at 202-789-6820.
The Commission gives notice that the Postal Service filed request(s) for the Commission to consider matters related to negotiated service agreement(s). The request(s) may propose the addition or removal of a negotiated service agreement from the market dominant or the competitive product list, or the modification of an existing product currently appearing on the market dominant or the competitive product list.
Section II identifies the docket number(s) associated with each Postal Service request, the title of each Postal Service request, the request's acceptance date, and the authority cited by the Postal Service for each request. For each request, the Commission appoints an officer of the Commission to represent the interests of the general public in the proceeding, pursuant to 39 U.S.C. 505 (Public Representative). Section II also establishes comment deadline(s) pertaining to each request.
The public portions of the Postal Service's request(s) can be accessed via the Commission's Web site (
The Commission invites comments on whether the Postal Service's request(s) in the captioned docket(s) are consistent with the policies of title 39. For request(s) that the Postal Service states concern market dominant product(s), applicable statutory and regulatory requirements include 39 U.S.C. 3622, 39 U.S.C. 3642, 39 CFR part 3010, and 39 CFR part 3020, subpart B. For request(s) that the Postal Service states concern competitive product(s), applicable statutory and regulatory requirements include 39 U.S.C. 3632, 39 U.S.C. 3633, 39 U.S.C. 3642, 39 CFR part 3015, and 39 CFR part 3020, subpart B. Comment deadline(s) for each request appear in section II.
1.
Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (the “Act”),
The text of the proposed rule change is available on the Exchange's Web site (
In its filing with the Commission, the Exchange included statements concerning the purpose of and basis for the proposed rule change and discussed any comments it received on the proposed rule change. The text of these statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant aspects of such statements.
The Exchange proposes to amend its Fees Schedule. Particularly, the Exchange proposes to amend its fees for Firm (origin codes “F” and “L”) facilitation orders. The Fees Schedule currently defines “Facilitation orders” as any order in which a Clearing Trading Permit Holder (“F” origin code) or Non-Trading Permit Holder Affiliate (“L” origin code) is contra to any other origin code, provided the same executing broker and clearing firm are on both sides of the transaction (for open outcry) or both sides of a paired order (for orders executed electronically).
The Exchange believes the proposed rule change is consistent with the Securities Exchange Act of 1934 (the “Act”) and the rules and regulations thereunder applicable to the Exchange and, in particular, the requirements of Section 6(b) of the Act.
The Exchange believes that assessing $0.05 per contract for Firm facilitation orders executed via AIM (
The Exchange believes that assessing $0.17 per contract for Firm facilitation orders executed as a QCC order is reasonable because it is the same amount all non-Customer orders are assessed for QCC order executions. The Exchange believes it is equitable and not unfairly discriminatory to no longer waive transaction fees for QCC facilitation contra orders because QCC orders already receive a rebate of $0.10 per contract. The Exchange also notes that transaction fees for similar QCC facilitation orders executed at other exchanges are not waived.
The Exchange does not believe that the proposed rule changes will impose any burdens on competition that are not necessary or appropriate in furtherance of the purposes of the Act. The Exchange does not believe that the proposed rule change will impose any burden on intramarket competition that is not necessary or appropriate in furtherance of the purposes of the Act because while the Exchange is eliminating its Firm Facilitation fee waiver for AIM and QCC orders, these orders are subject to the benefit of various rebates and will be assessed the same amounts charged to Firms for non-facilitation AIM contra orders and QCC orders, respectively. The Exchange does not believe that the proposed change will cause any unnecessary burden on intermarket competition because the proposed change only affects trading on CBOE. To the extent that the proposed changes make CBOE a more attractive marketplace for market participants at other exchanges, such market participants are welcome to become CBOE market participants.
The Exchange neither solicited nor received comments on the proposed rule change.
The foregoing rule change has become effective pursuant to Section 19(b)(3)(A) of the Act
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Brent J. Fields, Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Pursuant to the provisions of Section 19(b)(1) of the Securities Exchange Act of 1934 (“Act”)
The Exchange is filing a proposal to amend Exchange Rule 519A, Risk Protection Monitor.
The text of the proposed rule change is available on the Exchange's Web site at
In its filing with the Commission, the Exchange included statements concerning the purpose of and basis for the proposed rule change and discussed any comments it received on the proposed rule change. The text of these statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant aspects of such statements.
The Exchange proposes to amend Exchange Rule 519A, Risk Protection Monitor, to mandate the use of the Risk Protection Monitor by Members, and to state clearly in the rule that Members may establish multiple RPM Settings, as defined below.
Currently, using the Risk Protection Monitor, the Exchange's System
Under the current rule, Members may establish an Allowable Order Rate
When engaged, the Risk Protection Monitor allows the Member to interact with existing orders entered prior to triggering the Risk Protection Monitor and allows the Member to continue to send cancel messages and receive reports of executions resulting from those orders. The Risk Protection Monitor shall remain engaged until the Member communicates with the Exchange staff to enable the acceptance of new orders.
First, the Exchange proposes to amend current Rule 519A(a) and (b) by consolidating the two paragraphs into one unified, cohesive paragraph describing the Risk Protection Monitor feature, its functionality, the ability of Members to establish and configure multiple Risk Protection Monitor settings, and the ability of Members to determine one of three alternative actions taken by the Risk Protection Monitor once it is triggered.
Proposed Rule 519A will continue to include the basic description of the Risk Protection Monitor described above. The proposed amendments will reflect that the Risk Protection Monitor maintains one or more Member-configurable Allowable Order Rate settings and Allowable Contract Execution Rate settings (collectively, “Risk Protection Monitor settings”). The Exchange believes that providing Members with the ability to establish multiple Risk Protection Monitor settings enhances Members' ability to account for sudden market movements due to extreme market volatility, and for heightened activity in one particular option or group of options in a particular industry or segment of the market due to news or other factors affecting the activity surrounding such option or options. Members may also simultaneously account for normal or even sluggish activity in less active options by establishing higher Risk Protection Monitor settings and a longer specified time period during which the Risk Protection Monitor engages the counting program.
Amended Rule 519A(a), Voluntary Risk Protection Functionality,
The Exchange believes that the ability of a Member to choose among three outcomes once the Risk Protection Monitor is triggered enhances the risk protections afforded to Members by the Exchange and thus provides a tool by which Members can further use the Risk Protection Monitor, once triggered, by tailoring the outcome to their acceptable risk tolerance levels.
In addition to the consolidation of current Rules 519A(a) and (b) into one paragraph (new paragraph (a)), the Exchange proposes to adopt new Rule 519A(b), Mandatory Participation, to state that Members must establish at least one Allowable Order Rate setting with a corresponding specified time period of not less than one second, and not to exceed ten seconds, as established by the Exchange and communicated to Members via Regulatory Circular (a “Corresponding Specified Time Period”) and at least one Allowable Contract Execution Rate setting (with a Corresponding Specified Time Period). The Exchange believes that establishing the Corresponding Specified Time Period within these parameters will provide minimum and maximum guidelines for Members, making their required use of the Risk Protection Monitor more efficient and streamlined.
The Risk Protection Monitor settings must be configured by the Member such that the Risk Protection Monitor, when triggered, will perform one of two steps set forth in proposed Rule 519A(a): Either (A) prevent the System from receiving any new orders in all series in all classes from the Member; or (B) prevent the System from receiving any new orders in all series in all classes from the Member and cancel all existing orders with a time-in-force of Day in all series in all classes from the Member. Under the mandatory provision of proposed Rule 519A(b), the simple Member notification option included in section (C) of proposed Rule 519A(a) would not be available.
The purpose of this proposed provision is to mandate the use of the Risk Protection Monitor so that Members and the investing public are assured that the Risk Protection Monitor is active for all orders submitted to the
Proposed Rule 519A(b) would also state that Members may establish additional Allowable Order Rate settings and additional Allowable Contract Execution Rate settings, and any such additional settings may be configured to perform the step set forth in either (A), (B), or (C) of Rule 519(a) as described above, upon engagement of the Risk Protection Monitor.
As a technical matter, the Exchange proposes to amend Rule 519A, Interpretations and Policies .01(c), to make it consistent with the proposed amended Rule. The current Rule states that the Risk Protection Monitor will prevent the System from receiving any new orders in all series in all classes from the Member and, if designated by the Member's instructions, cancel all existing Day orders in all series in all classes from the Member. “Day orders” are not defined in the Exchange's rules and therefore the Exchange proposes to replace the term “Day orders” with “orders with a time-in-force of Day.”
The purpose of the proposed rule change is to enhance the risk protections afforded to Members by the Exchange by mandating use of the RPM and by permitting Members to establish multiple RPM Settings which can be tailored to the Member's acceptable risk tolerance levels.
The Exchange anticipates that the proposed new Risk Protection Monitor functionality will be deployed on the Exchange beginning November 7, 2016.
MIAX believes that its proposed rule change is consistent with Section 6(b) of the Act
The Exchange believes that Members will benefit from the proposed mandatory use of the Risk Protection Monitor, coupled with the ability of members to tailor their use of the Risk Protection Monitor to their risk tolerance levels. Members are vulnerable to the risk from system or other error or a market event, that may cause them to send a large number of orders or receive multiple, automatic executions before they can adjust their order exposure in the market. Without adequate risk management tools, such as the Risk Protection Monitor, Members could reduce the amount of order flow and liquidity that they provide to the market. Such actions may undermine the quality of the markets available to customers and other market participants. Accordingly, the proposed amendments to the Risk Protection Monitor, especially its mandated use, should instill additional confidence in Members that submit orders to the Exchange that their risk tolerance levels are protected, and thus should encourage such Members to submit additional order flow and liquidity to the Exchange with the understanding that they must have this protection, thereby removing impediments to and perfecting the mechanisms of a free and open market and a national market system and, in general, protecting investors and the public interest.
In addition, providing Members with the ability to establish multiple RPM settings provides Members with more tools to use in managing their specific risks based on their individual risk tolerance levels. This facilitates transactions in securities because, as noted above, the Members will have more confidence that protections are in place that reduce the risks from potential system errors and market events. As a result, the modified functionality, together with the mandated use of the Risk Protection Monitor, has the potential to promote just and equitable principles of trade.
The Exchange does not believe that the proposed rule change will impose any burden on competition that is not necessary or appropriate in furtherance of the purposes of the Act. On the contrary, the Exchange believes that the amendments to the Risk Protection Monitor help promote competition by enabling Members to trade more aggressively on the Exchange, with the understanding that there are multiple, configurable risk management tools in place in the System. The Exchange believes the proposed changes will not impose any burden on intra-market competition because the use of the Risk Protection Monitor is now required of all Members.
The Exchange further believes that the proposed mandatory risk protections should promote inter-market competition, and result in more competitive order flow to the Exchange by protecting market participants from system errors or market events that may cause them to send a large number of orders or receive multiple, automatic executions before they can adjust their order exposure in the market.
Written comments were neither solicited nor received.
Because the foregoing proposed rule change does not: (i) Significantly affect the protection of investors or the public interest; (ii) impose any significant burden on competition; and (iii) become operative for 30 days after the date of the filing, or such shorter time as the Commission may designate, it has become effective pursuant to 19(b)(3)(A) of the Act
A proposed rule change filed under Rule 19b-4(f)(6) normally does not become operative prior to 30 days after the date of filing. However, Rule 19b-4(f)(6)(iii)
At any time within 60 days of the filing of the proposed rule change, the Commission summarily may temporarily suspend such rule change if it appears to the Commission that such action is necessary or appropriate in the public interest, for the protection of investors, or otherwise in furtherance of the purposes of the Act. If the Commission takes such action, the Commission shall institute proceedings to determine whether the proposed rule should be approved or disapproved.
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
On August 4, 2016, NASDAQ PHLX LLC (“Phlx” or “Exchange”) filed with the Securities and Exchange Commission (the “Commission”), pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (the “Act”)
The Exchange has proposed to reorganize and amend current Rule 1017, which describes the opening of trading in option series on the Exchange.
The Exchange proposes to revise the introductory language to Rule 1017(a) to state that it would conduct an electronic opening for all option series traded on Phlx using its trading system (“system”).
• “ABBO” as the Away Best Bid or Offer;
• “Phlx Electronic Market Maker” as a Specialist,
• “Pre-Market BBO” as the highest bid and lowest offer among Valid Width Quotes;
• “Quality Opening Market” as the bid/ask differential applicable to the best bid and offer from all Valid Width Quotes defined in a table to be determined by the Exchange and published on the Exchange's Web site;
• “Valid Width Quote” as the two-sided electronic quotation submitted by a Phlx Electronic Market Maker that consists of a bid/ask differential that is compliant with Rule 1014(c)(i)(A)(1)(a);
• “Zero Bid Market” as where the best bid for an options series is zero.
In addition, the Exchange proposes to define the “market for the underlying security” as either the primary listing market or the primary volume market (defined as the market with the most liquidity in that underlying security for the previous two calendar months), as determined by the Exchange by underlying and announced to the Exchange's membership on the Exchange's Web site.
Under the proposal, eligible interest during the Opening Process would include Valid Width Quotes, Opening Sweeps,
The proposed rule provides that a Phlx Electronic Market Maker assigned in a particular option may only submit an Opening Sweep if, at the time of entry of the Opening Sweep, that Phlx Electronic Market Maker has already submitted and maintained a Valid Width Quote. All Opening Sweeps in the affected series entered by a Phlx Electronic Market Maker would be cancelled immediately if that Phlx Electronic Market Maker fails to maintain a continuous quote with a Valid Width Quote in the affected series.
Currently, the Phlx rules provide that the system will use only Opening Sweeps submitted by Phlx Electronic Market Makers to determine the pro-rata allocation.
Under proposed Rule 1017(d), the Opening Process for an option series would be conducted pursuant to Rule 1017(f)-(k) on or after 9:30 a.m. if: (1) The ABBO, if any, is not crossed; and (2) the system has received, within two minutes of the opening trade or quote on the market for the underlying security in the case of equity options or, in the case of index options, within two minutes of the receipt of the Opening Price in the underlying index, or within two minutes of market opening in the case of U.S. dollar-settled foreign currency options, either:
(a) The Specialist's Valid Width Quote;
(b) the Valid Width Quotes of at least two Phlx Electronic Market Makers other than the Specialist; or
(c) if neither the Specialist's Valid Width Quote nor the Valid Width Quotes of two Phlx Electronic Market Makers have been submitted within such timeframe, one Phlx Electronic Market Maker has submitted a Valid Width Quote.
The Exchange proposes that for all options, the underlying security, including indexes, must be open on the primary market for a certain period of time as determined by the Exchange, which shall be no less than 100 milliseconds and no more than 5 seconds.
Under proposed Rule 1017(d)(iii), the Specialist assigned in a particular equity option must enter a Valid Width Quote
As proposed, the Opening Process would stop and an option series would not open if the away best bid or offer (“ABBO”) becomes crossed or when the requisite number of Valid Width Quotes pursuant to Rule 1017(d)(i) is no longer present. The Exchange states that it would wait for the ABBO to become uncrossed before initiating the Opening Process to ensure that there is stability in the marketplace as the Exchange determines the Opening Price.
Under proposed Rule 1017(f), if there are no opening quotes or orders that lock or cross each other and no routable orders locking or crossing the ABBO, Phlx would open with an opening quote by disseminating the Exchange's best bid and offer among quotes and orders (“PBBO”) that exist in the system at that time, unless the following three conditions exist: (i) A Zero Bid Market; (ii) no ABBO; and (iii) no Quality Opening Market. If all of these conditions exist, the Exchange would calculate an Opening Quote Range (“OQR”) and conduct the price discovery mechanism (“PDM”).
Pursuant to proposed Rule 1017(g), the system would calculate a Pre-Market BBO if there are opening Valid Width Quotes or orders that lock or cross each other. The Exchange represents that this is provided for in the current rule text.
Proposed Rule 1017(h) describes how the system calculates the Potential Opening Price once the Opening Process begins.
Under proposed Rule 1017(h)(A), when two or more Potential Opening Prices would satisfy the maximum quantity criterion and leave no contracts unexecuted, the system would use the highest and lowest of those prices to calculate the mid-point. If the mid-point is not expressed as a permitted minimum price variation, it would be rounded to the minimum price variation that is nearest to the closing price for the affected series from the immediate prior trading session. If there is no closing price from the immediate prior trading session, the system would round the mid-point price up to the minimum price variation to determine the Opening Price. The Exchange states that this is similar to current Rule 1017(l)(ii)(B), but the Exchange has added that this method of calculating the Opening Price would occur where two or more Potential Opening Prices would leave no contracts unexecuted.
Under proposed Rule 1017(h)(B), the Exchange would add that if two or more Potential Opening Prices for the affected series would satisfy the maximum quantity criterion and leave contracts unexecuted, the Opening Price would be either the lowest executable bid or highest executable offer of the largest sized side. This is designed to base the Potential Opening Price on the maximum quantity of contracts that are executable.
Under proposed Rule 1017(i), the Exchange would open the option series for trading at the following Opening Price if: (1) The Potential Opening Price is at or within the best of the Pre-Market BBO and the ABBO; (2) the Potential Opening Price is at or within the non-zero bid ABBO if the Pre-Market BBO is crossed; or (3) where there is no ABBO, the Potential Opening Price is at or within the Pre-Market BBO that is also a Quality Opening Market. If there is more than one Potential Opening Price that would meet these conditions where no contracts would be left unexecuted and any value used for the mid-point calculation crosses either the Pre-Market BBO or the ABBO, then the Exchange would open the option series for trading and use the best price that the Potential Opening Price crosses outside as a boundary price for the purposes of the mid-point calculation. The Exchange states that the purpose of these boundaries is to help ensure that the Potential Opening Price is reasonable and does not trade through other markets.
The Exchange proposes that the system would calculate an OQR for an option series that would be used in the PDM.
Under proposed Rule 1017(j)(5), if there is more than one Potential Opening Price possible where no contracts would be left unexecuted, any Potential Opening Price used for the mid-point calculation (described in Rule 1017(h)) that is outside the OQR would be restricted to the OQR price on that side of the market for the purposes of the mid-point calculation. Proposed Rule 1017(j)(6) would provide that if there is more than one Potential Opening Price possible where no contracts would be left unexecuted and any price used for the mid-point calculation (described in Rule 1017(h)) is an away market price when contracts would be routed, the system would use the away market price as the Potential Opening Price. The Exchange states that it uses the away market price as the Opening Price because the system may need to route to other markets.
Current Rule 1017(l)(vi), which the Exchange proposes to delete, provides that if all opening marketable size cannot be completely executed at or within the OQR without trading through the ABBO, the Exchange would conduct a price discovery process. Under proposed Rule 1017(k), the Exchange would conduct the PDM, after the OQR calculation, if it has not opened pursuant to the processes described in Rule 1017(f) or (i). According to the Exchange, the purpose of the PDM is to satisfy the maximum number of contracts possible by applying wider price boundaries and seeking additional liquidity.
Under the proposal, first, the Exchange would broadcast an imbalance message (including the symbol, side of the imbalance (unmatched contracts), size of matched contracts, size of the imbalance, and price of the affected series, which must be within the Pre-Market BBO) to participants (“Imbalance Message”), and begin an “imbalance timer” (“Imbalance Timer”) that would not exceed three seconds and would be for the same number of seconds for all options traded on the Exchange. The Exchange notes that this provision is the same as in the existing rule, except that the Exchange is adding the requirement that the Imbalance Message must be within the Pre-Market BBO to ensure that the price is reasonable.
Under proposed Rule 1017(k)(B), any new interest received by the system would then update the Potential Opening Price. If during or at the end of the Imbalance Timer, the Opening Price is at or within the OQR, the Imbalance Timer would end and the system would execute at the Opening Price. However, this would occur only if the executions consist of Exchange interest only without trading through: (1) The ABBO and (2) the limit price(s) of interest within the OQR that is unable to be fully executed at the Opening Price. Under the proposal, if no new interest comes in during the Imbalance Timer, and the Opening Price is at or within the OQR, the Exchange would open at the end of the Imbalance Timer.
If the option series has not opened pursuant to proposed Rule 1017(k)(B), the system would (1) send a second Imbalance Message with a Potential Opening Price that is bounded by the OQR (without trading through the limit price(s) of interest within the OQR which is unable to be fully executed at the Opening Price) and includes away market volume in the size of the imbalance to participants; and concurrently (2) initiate a route timer, not to exceed one second (“Route Timer”). Current Rule 1017(l)(ii)(C) provides that if the Exchange's opening price includes away interest, the system would initiate a route timer, and then subsequently route to other markets disseminating prices better than the Exchange's opening price, execute marketable interest at the Exchange's opening price, and route to other markets disseminating prices equal to the Exchange's opening price if necessary. However, under the proposed rule change, the Route Timer would be initiated during the imbalance process.
The Exchange states that the Route Timer is intended to give participants an opportunity to respond to an Imbalance Message before any opening interest is routed to away markets and thereby, maximize trading on the Exchange.
Proposed Rule 1017(k)(C)(3) would provide that when the Route Timer expires, if the Potential Opening Price is within the OQR (without trading through the limit price(s) of interest within the OQR that is unable to be fully executed at the Opening Price), the system would determine if the total number of contracts displayed at better
Pursuant to proposed Rule 1017(k)(C)(3)(i), if the total number of better priced away contracts would satisfy the number of marketable contracts available on the Exchange on either the buy or sell side, the system would route all marketable contracts on the Exchange to the better priced away markets as an intermarket sweep order (“ISO”) designated as an immediate-or-cancel order(s) (“IOC”), and determine an opening PBBO that reflects the interest remaining on the Exchange. In contrast with the current rule, which states that contracts routed away are priced at the better away market price, under the proposed rule, the system would price any contracts routed away to other markets at the Exchange's Opening Price.
Under proposed Rule 1017(k)(C)(3)(ii), if the total number of better priced away contracts would not satisfy the number of marketable contracts the Exchange has, the system would determine how many contracts it has available at the Opening Price. If the total number of better priced away contracts plus the number of contracts available at the Opening Price would satisfy the number of marketable contracts on the Exchange on either the buy or sell side, the system would contemporaneously route a number of contracts that would satisfy interest at other markets at prices better than the Opening Price and trade available contracts on the Exchange at the Opening Price. The system would price any contracts routed to other markets at the better of the Opening Price or the order's limit price pursuant to Rule 1017(k)(C)(3)(ii) at the Opening Price. Under the current rules of the Exchange, the Exchange will execute only at the Opening Price, and does not specify that the system would use the better of the Opening Price or the order's limit price to route to away markets. The Exchange states that this proposed Rule 1017(k)(C)(3)(ii) is designed to maximize execution of interest on the Exchange or away markets.
Proposed Rule 1017(k)(C)(3)(iii) provides that if the total number of better priced away contracts plus the number of contracts available at the Opening Price plus the contracts available at other markets at the Opening Price would satisfy the number of marketable contracts the Exchange has on either the buy or sell side, the system would contemporaneously route a number of contracts that would satisfy interest at other markets at prices better than the Opening Price (pricing any contracts routed to other markets at the better of the Opening Price or the order's limit price), trade available contracts on the Exchange at the Opening Price, and route a number of contracts that would satisfy interest at other markets at prices equal to the Opening Price. The Exchange notes that the proposed rule adds a reference to the order's limit price. The Exchange states that routing at the better of the Opening Price or the order's limit price is intended to achieve the best possible price available at the time the order is received by the away market and that routing at the order's limit price ensures that the order's limit price is not violated.
Under proposed Rule 1017(k)(C)(4), after the first and second Imbalance Messages, each of which would be set for the same amount of time and would last for the length of the Imbalance Timer, the system may send up to two additional Imbalance Messages (which may occur while the Route Timer is operating) bounded by the OQR and reflecting away market interest in the volume. After the Route Timer has expired, the processes in Rule 1017(k)(C)(3) would repeat. However, unlike as provided in current Rule 1017(l)(vii)(C)(6), a new Route Timer would not be initiated.
The Exchange proposes that, pursuant to proposed Rule 1017(k)(C)(5), after all additional Imbalance Messages have occurred pursuant to proposed Rule 1017(k)(C)(4), the system would open as many contracts as possible by routing to other markets at prices better than the Opening Price for their disseminated size, trading available contracts on the Exchange at the Opening Price bounded by the OQR (without trading through the limit price(s) of interest within the OQR which is unable to be fully executed at the Opening Price), and routing contracts to other markets at prices equal to the Opening Price at their disseminated size. In this situation, the system would price any contracts routed to other markets at the better of the Opening Price or the order's limit price. Any unexecuted contracts from the imbalance not traded or routed would be cancelled back to the entering participant if they remain unexecuted and priced through the Opening Price, unless the member that submitted the original order has instructed the Exchange in writing to re-enter the remaining size, in which case the remaining size would be automatically submitted as a new order. The Exchange notes that this is similar to the text of the current rule, but that the Exchange is deleting text that provides that before an order is cancelled back or re-entered, it would be displayed in the Exchange's quote at the Opening Price for the remaining size for a period not to exceed ten seconds.
Under proposed Rule 1017(k)(C)(6), the system would execute orders at the Opening Price that have contingencies (such as, without limitation, all-or-none) and non-routable orders, such as a “Do Not Route” or “DNR” Orders, to the extent possible.
Under the proposed rule change, the system would give priority to market orders first in time priority, then resting limit orders, and the allocation
The Exchange also proposes to delete current Rule 1017(l)(ix), which provides for a delay to calculate the opening. The Exchange's current technology does not require a delay in order to open, and the Exchange states that therefore, this requirement is obsolete.
After careful review, the Commission finds that the proposed rule change, as modified by Partial Amendment No. 2, is consistent with the requirements of the Act and the rules and regulations thereunder applicable to a national securities exchange.
The Commission notes that, generally, the Exchange is proposing changes to the definitions described in Section II.A to better organize and clearly convey for readers existing concepts that are throughout the Exchange's Opening Process rules. The Commission notes that the Exchange is proposing to eliminate from the definition of “market for the underlying security” under Rule 1017(a)(v) the phrase the “first market to open.” The Exchange represents that it does not currently use the first market to open to determine the market for the underlying security and will only use the primary listing market and primary volume market to determine the underlying market.
The Commission notes that the Exchange is proposing that all-or-none interest that can be satisfied would be considered for execution and in determining the Opening Price throughout the Opening Process. The Exchange is also proposing to aggregate the size of all eligible interest for a particular participant category at a particular price level to determine the pro-rata allocation
As discussed in Section II.C, proposed Phlx Rule 1017(d) sets forth the Opening Process for an option series, which the Exchange represents is the same as the requirements under current Rule 1017(k). The Exchange represents that throughout the Opening Process, there will be no different impact to any particular participants and that executions occur at the most reasonable price possible regardless of participant type.
The Commission believes that the Exchange's proposal to provide a delay between the opening of the underlying and the related option is not novel
Lastly, new Rule 1017(e) states that the procedure described in Rule 1017 may be used to reopen an option after a trading halt. This concept is currently in Rule 1017(h) except that the Exchange is adding that if there is a trading halt or pause in the underlying security, the Opening Process would start again irrespective of the specific times listed in Rule 1017(d). The Commission notes that the times listed in Rule 1017(d) relate to the normal market opening at 9:30 a.m. and thus would not be appropriate for re-openings, which do not occur at the beginning of the trading day. The
As discussed in Section II.D, the Exchange is proposing that it would open with an opening quote by disseminating the PBBO only if there are no opening quotes or orders that lock or cross each other and no routable orders locking or crossing the ABBO. The Commission notes that this proposed change comports with the Exchange's existing rules,
As discussed in Section II.F, the Exchange is proposing that in calculating the Potential Opening Price, the system would consider all Valid Width Quotes, Opening Sweeps, and orders, except all-or-none interest that cannot be satisfied, and identify the maximum quantity criterion. The Commission believes that specifying the interest considered in determining the Potential Opening Price would allow market participants to better understand the operation of the rule. The Exchange is proposing that when two or more Potential Opening Prices would both satisfy the maximum quantity criterion and leave no contracts unexecuted, the system would take the highest and lowest of those prices and take the mid-point. The Commission notes that this is based on current Phlx Rule 1017(l)(ii)(B). The Commission believes that the Exchange's proposal to use the lowest executable bid or the highest executable offer of the largest sized order in the event of a tie among Potential Opening Prices that would satisfy the maximum quantity criteria and leave contracts unexecuted could provide for more orderly opening. As further discussed in Section II.F, the Exchange has also proposed that the Potential Opening Price would be bounded by the away market price that could not be satisfied with the Exchange routable interest, which is designed to prevent opening with a trade that would trade through another market.
As discussed above in Section II.G, the proposal describes the conditions under which the Exchange would open with a trade using certain price boundaries for the Potential Opening Price. The Commission notes that the conditions specified in Rule 1017(i) are designed to identify a reasonable Opening Price for an options series to open on the Exchange without trading through the prices of other markets.
As described in Section II.H, the Exchange is proposing to add additional criteria to the OQR, which is applied as a boundary during the PDM. According to the Exchange, the OQR is designed to act as a protection for the Opening Price because it protects away market prices and also protects against extreme volatility, which impacts the Opening Price.
The PDM seeks to identify an Opening Price if the Exchange has not already done so through the processes provided in 1017(f) and (i). The PDM is designed to attract liquidity to improve the price at which an options series will open and maximize the number of contract that can be executed at the opening.
The Commission notes that the Exchange's proposal to handle limit orders in the same manner at the opening as throughout the rest of the trading day is consistent with the practices of other exchanges, which do not provide that limit orders would be treated differently at different times in the trading day.
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether Partial Amendment No. 2 to the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
The Commission finds good cause to approve the proposed rule change, as modified by Partial Amendment No. 2, prior to the 30th day after the date of publication of notice of Partial Amendment No. 2 in the
Partial Amendment No. 2 supplements the proposed rule change by, among other things, clarifying the interest included in the Opening Process and providing additional explanation and detail about several aspects of the Exchange's Opening Process. It also helps the Commission evaluate whether the proposed rule change would be consistent with the protection of investors and the public interest.
Accordingly, the Commission finds good cause, pursuant to Section 19(b)(2) of the Act,
It is therefore ordered, pursuant to Section 19(b)(2) of the Act,
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (“Act”),
The Exchange proposes to amend the Exchange's NBBO Program at Rule 7014(g) to change the qualification criteria required to receive the $0.0004 per share executed NBBO Program rebate in NYSE-listed securities and in Securities Listed on Exchanges other than Nasdaq and NYSE.
The text of the proposed rule change is available on the Exchange's Web site at
In its filing with the Commission, the Exchange included statements concerning the purpose of and basis for the proposed rule change and discussed any comments it received on the proposed rule change. The text of these statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant aspects of such statements.
The purpose of the proposed rule change is to amend the Exchange's NBBO Program at Rule 7014(g) to change the qualification criteria required to receive the $0.0004 per share executed NBBO Program rebate in NYSE-listed securities and in Securities Listed on Exchanges other than Nasdaq and NYSE. The NBBO Program provides two rebates per share executed with respect to all other displayed orders (other than Designated Retail Orders, as defined in Rule 7018) in securities priced at $1 or more per share that provide liquidity, establish the NBBO,
The Exchange is proposing to amend one of the data points used in the calculation of the ratio required for a port to qualify for the $0.0004 per share executed NBBO Program rebate to now compare liquidity provided by displayed quotes/orders (other than Supplemental Orders or Designated Retail Orders) to NBBO liquidity provided. Thus, the Exchange is using a more limited category of liquidity (
The Exchange believes that its proposal is consistent with Section 6(b) of the Act,
The Exchange believes that the proposed change is an equitable allocation and is not unfairly discriminatory because it makes it easier to qualify for the rebate. As a consequence, the Exchange is making the rebate more achievable for members, which may in turn, attract new members to the program. The Exchange notes that the program rewards members that provide liquidity that sets the NBBO, thus improving the market for all participants. To the extent the proposed change is successful in attracting more members to participate in the program, all participants will benefit from the increased competition in setting the NBBO. The Exchange further notes that a member that currently qualifies for the rebate would qualify for the rebate under the amended criteria. Last, the proposed change does not alter the amount of the rebate provided. Thus, the Exchange believes that the amount of the rebate continues to be reasonable for the reasons stated by the Exchange when the rebate was adopted.
The Exchange does not believe that the proposed rule change will impose any burden on competition not necessary or appropriate in furtherance of the purposes of the Act. In terms of inter-market competition, the Exchange notes that it operates in a highly competitive market in which market participants can readily favor competing venues if they deem fee levels at a particular venue to be excessive, or rebate opportunities available at other venues to be more favorable. In such an environment, the Exchange must continually adjust its fees to remain competitive with other exchanges and with alternative trading systems that have been exempted from compliance with the statutory standards applicable to exchanges. Because competitors are free to modify their own fees and rebates in response, and because market participants may readily adjust their order routing practices, the Exchange believes that the degree to which fee changes in this market may impose any burden on competition is extremely limited.
In this instance, the proposed changes to the criteria required of members to receive a rebate under the NBBO Program make it easier for members to qualify for a rebate under the program, with the intent of making the program more attractive to members. Thus, the proposed change promotes competition for order flow among trading venues, and does not impose a burden on competition because the Exchange's execution services are completely voluntary and subject to extensive competition both from other exchanges and from off-exchange venues, which may provide similar incentives to their members. In sum, if the changes proposed herein are unattractive to market participants, it is likely that the Exchange will lose market share as a result. Accordingly, the Exchange does not believe that the proposed changes will impair the ability of members or competing order execution venues to maintain their competitive standing in the financial markets.
No written comments were either solicited or received.
The foregoing rule change has become effective pursuant to Section 19(b)(3)(A)(ii) of the Act.
At any time within 60 days of the filing of the proposed rule change, the Commission summarily may temporarily suspend such rule change if it appears to the Commission that such action is: (i) Necessary or appropriate in the public interest; (ii) for the protection of investors; or (iii) otherwise in furtherance of the purposes of the Act. If the Commission takes such action, the Commission shall institute proceedings to determine whether the proposed rule should be approved or disapproved.
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Pursuant to Section 19(b)(1)
The Exchange proposes to temporarily widen price collar thresholds for the Core Open Auction and Trading Halt Auctions, which would be operative on November 9, 2016 only. The proposed rule change is available on the Exchange's Web site at
In its filing with the Commission, the self-regulatory organization included statements concerning the purpose of, and basis for, the proposed rule change and discussed any comments it received on the proposed rule change. The text of those statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant parts of such statements.
The Exchange proposes to temporarily widen price collar thresholds for the Core Open Auction and Trading Halt Auctions, which would be operative for November 9, 2016 only.
On November 8, 2016, the United States held an election to decide, among other things, the next President of the United States. This election result has caused market volatility. This spike in market volatility has also impacted the pricing of Exchange Traded Products (“ETP”), the majority of which are listed on the Exchange.
Because of the level of market volatility, the Exchange believes that widening the Auction Collars for the Core Open Auction and Trading Halt Auctions for November 9, 2016 only would assist the Exchange in conducting fair and orderly auctions.
As set forth in Rule 7.35(a)(10), the price collar thresholds for the Core Open Auction and Trading Halt Auctions are currently set at 10% for securities with an Auction Reference Price of $25.00 or less, 5% for securities with an Auction Reference Price greater than $25.00 but less than or equal to $50.00, and 3% for securities with an Auction Reference Price greater than $50.00.
The Exchange proposes to apply Auction Collars of 10% for all Auction-Eligible Securities,
The proposed rule change is consistent with Section 6(b) of the Act,
In particular, the Exchange believes that the impact of the results of the presidential election on November 8, 2016 has resulted in global market volatility and the U.S. ETP market is not immune. In response to this market volatility, the Exchange believes that it would promote the protection of investors and the public interest to temporarily widen the price collar thresholds for the Core Open Auction and Trading Halt Auctions on November 9, 2016 only because it would promote fair and orderly auctions. The Exchange further believes that widening the price collar thresholds would remove impediments to and perfect the mechanism of a national market system because it is designed to allow for greater price movement, while at the same time preventing auction trades from occurring at prices significantly away from the applicable Auction Reference Price. Accordingly, investors would be protected from executions significantly away from the last sale in a security or other applicable reference price, but natural price fluctuations resulting from the market volatility would be permitted. In addition, the Exchange believes that widening the Auction Collars could reduce the possibility of securities triggering multiple trading pauses under the Regulation NMS Plan to Address Market Volatility.
The Exchange does not believe that the proposed rule change would impose any burden on competition that is not necessary or appropriate in furtherance of the purposes of the Act. The proposed rule change is not designed to address any competitive issues but rather is designed to ensure a fair and orderly market by temporarily widening the price collar thresholds for the Core Open Auction and Trading Halt Auctions on a trading day with market volatility due to the results of the presidential election, In addition, the proposed rule change is intended to be in effect for November 9, 2016 only to respond to unique events relating to U.S. presidential election and therefore will not create a burden on competition.
No written comments were solicited or received with respect to the proposed rule change.
Because the proposed rule change does not (i) significantly affect the protection of investors or the public interest; (ii) impose any significant burden on competition; and (iii) become operative for 30 days from the date on which it was filed, or such shorter time as the Commission may designate, it has become effective pursuant to Section 19(b)(3)(A) of the Act
A proposed rule change filed pursuant to Rule 19b-4(f)(6) under the Act
At any time within 60 days of the filing of the proposed rule change, the Commission summarily may temporarily suspend such rule change if it appears to the Commission that such action is necessary or appropriate in the public interest, for the protection of investors, or otherwise in furtherance of the purposes of the Act. If the Commission takes such action, the Commission shall institute proceedings to determine whether the proposed rule change should be approved or disapproved.
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Brent J. Fields, Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (the “Act”),
The Exchange filed a proposal to amend the fee schedule applicable to Members
In its filing with the Commission, the Exchange included statements concerning the purpose of and basis for the proposed rule change and discussed any comments it received on the proposed rule change. The text of these statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in Sections A, B, and C below, of the most significant parts of such statements.
The Exchange proposes to amend its fee schedule to specify in new footnote 5 that when Customer
The Exchange recently amended Rule 21.12 (Clearing Member Give Up) to expand upon the procedure related to the “give up” of a Clearing Member
The Exchange believes that the proposed rule change is consistent with the requirements of the Act and the rules and regulations thereunder that are applicable to a national securities exchange, and, in particular, with the requirements of Section 6 of the Act.
The Exchange notes that the U.S. options markets are highly competitive, and the proposed fee structure is intended to provide an incentive for Members utilizing the Exchange's new give up procedure to direct orders to the Exchange. The proposal would only apply to fee codes NC and PC, related to Customer orders, because these are the primary rebates in place on the Exchange
The Exchange believes that the proposed amendments to its fee
The Exchange believes its proposed amendments to its fee schedule would not impose any burden on competition that is not necessary or appropriate in furtherance of the purposes of the Act. The Exchange does not believe that the proposed change represents a significant departure from previous pricing offered by the Exchange or its competitors. Additionally, Members may opt to disfavor the Exchange's pricing if they believe that alternatives offer them better value. The Exchange believes that its proposal to incentivize Routing Firms that are utilizing the new give up procedure to direct Customer orders to the Exchange, and will enhance the Exchange's competitive position by resulting in increased liquidity on the Exchange, thereby providing more of an opportunity for customers to receive best executions.
The Exchange has not solicited, and does not intend to solicit, comments on this proposed rule change. The Exchange has not received any written comments from members or other interested parties.
The foregoing rule change has become effective pursuant to Section 19(b)(3)(A) of the Act
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Notice is hereby given, pursuant to the provisions of the Government in the Sunshine Act, Public Law 94-409, that the Securities and Exchange Commission will hold a closed meeting on Wednesday, November 16, 2016 at 1 p.m.
Commissioners, Counsel to the Commissioners, the Secretary to the Commission, and recording secretaries will attend the closed meeting. Certain staff members who have an interest in the matters also may be present.
The General Counsel of the Commission, or her designee, has certified that, in her opinion, one or more of the exemptions set forth in 5 U.S.C. 552b(c)(3), (5), (7), 9(B) and (10) and 17 CFR 200.402(a)(3), (a)(5), (a)(7), (a)(9)(ii) and (a)(10), permit consideration of the scheduled matter at the closed meeting.
Commissioner Piwowar, as duty officer, voted to consider the items listed for the closed meeting in closed session, and determined that no earlier notice thereof was possible.
The subject matter of the closed meeting will be:
Institution and settlement of injunctive actions;
Institution and settlement of administrative proceedings; and
Other matters relating to enforcement proceedings.
At times, changes in Commission priorities require alterations in the scheduling of meeting items.
For further information and to ascertain what, if any, matters have been added, deleted or postponed; please contact Brent J. Fields from the Office of the Secretary at (202) 551-5400.
Notice is hereby given, pursuant to the provisions of the Government in the
The forum will include remarks by SEC Commissioners and a panel discussion that Commissioners may attend. The panel discussion will explore how capital formation options are working for small businesses after the implementation of the JOBS Act. This Sunshine Act notice is being issued because a majority of the Commission may attend the meeting.
For further information, please contact Brent J. Fields from the Office of the Secretary at (202) 551-5400.
By virtue of the authority vested in the Secretary of State, including sections 1233 and 1513 of the National Defense Authorization Act for Fiscal Year 2008 (Pub. L. 110-181) (FY 2008 NDAA); 10 U.S.C. 127d; section 1226 of the National Defense Authorization Act for Fiscal Year 2016 (Pub. L. 114-92) (FY 2016 NDAA); and section 1 of the State Department Basic Authorities Act (22 U.S.C. 2651a), and delegated pursuant to Delegation of Authority 245-1, dated February 13, 2009, I hereby delegate to the Assistant Secretary for Political-Military Affairs, to the extent authorized by law, the authority to concur with the Secretary of Defense on the use of the Afghanistan Security Forces Fund pursuant to section 1513 of the FY 2008 NDAA; the use of the Global Lift and Sustain authority pursuant to 10 U.S.C. 127d; and the use of the Coalition Support Fund authority pursuant to section 1233 of the FY 2008 NDAA and section 1226 of the FY 2016 NDAA.
Notwithstanding this delegation of authority, any function or authority delegated by this Delegation may be exercised by the Secretary, the Deputy Secretary, the Deputy Secretary for Management and Resources, or the Under Secretary for Arms Control and International Security. Any reference in this delegation of authority to any statute or delegation of authority shall be deemed to be a reference to such statute or delegation of authority as amended from time to time.
This delegation of authority shall be published in the
Office of the United States Trade Representative.
Notice.
This notice is to inform the public of the availability of import statistics for the first nine months of 2016 relating to competitive need limitations (CNLs) under the Generalized System of Preferences (GSP) program. These import statistics identify some articles for which the 2016 trade levels may exceed statutory CNLs. Interested parties may find this information useful in deciding whether to submit a petition to waive the CNLs for individual beneficiary developing countries (BDCs) with respect to specific GSP-eligible articles.
Naomi Freeman at (202) 395-2974 or
The GSP program provides for the duty-free importation of designated articles when imported from designated BDCs. The GSP program is authorized by Title V of the Trade Act of 1974 as amended, 19 U.S.C. 2461,
Section 503(c)(2)(A) of the 1974 Act sets out the two different measures for CNLs. When the President determines that a BDC has exported to the United States during a calendar year either (1) a quantity of a GSP-eligible article having a value in excess of the applicable amount for that year ($175 million for 2016), or (2) a quantity of a GSP-eligible article having a value equal to or greater than 50 percent of the value of total U.S. imports of the article from all countries (50 percent CNL), the President must terminate GSP duty-free treatment for that article from that BDC by no later than July 1 of the next calendar year, unless the President grants a waiver before the exclusion goes into effect. CNLs do not apply to least-developed countries or beneficiaries of the African Growth and Opportunity Act.
Any interested party may submit a petition seeking a waiver of the 2016 CNL for individual beneficiary developing countries with respect to specific GSP-eligible articles. In addition, under section 503(c)(2)(F) of the 1974 Act, the President may waive the 50 percent CNL with respect to an eligible article imported from a BDC, if the value of total imports of that article from all countries during the calendar year did not exceed the applicable
Exclusions from GSP duty-free treatment where CNLs have been exceeded will be effective July 1, 2017, unless the President grants a waiver before the exclusion goes into effect. Exclusions for exceeding a CNL will be based on full 2016 calendar-year import statistics.
In order to provide advance notice of articles that may exceed the CNLs for 2016, the Office of the U.S. Trade Representative has compiled interim import statistics for the first nine months of 2016 relating to CNLs. This information can be viewed at:
Full calendar-year 2016 data for individual tariff subheadings will be available in February 2017 on the Web site of the U.S. International Trade Commission at
The interim 2016 import statistics are organized to show, for each article, the Harmonized Tariff Schedule of the United States (HTSUS) subheading and BDC of origin, the value of imports of the article from the specified country for the first nine months of 2016, and the corresponding share of total imports of that article from all countries. The list includes the GSP-eligible articles from BDCs that, based on interim nine-month 2016 data, exceed $110 million dollars, or an amount greater than 42 percent of
The list published on the USTR Web site includes the relevant nine-month trade statistics for each of these products and is provided as a courtesy for informational purposes only. The list is based on interim 2016 trade data, and may not include all articles that may be affected by the GSP CNLs. Regardless of whether or not an article is included on the list referenced in this notice, all determinations and decisions regarding application of the CNLs of the GSP program will be based on full calendar-year 2016 import data for each GSP-eligible article. Each interested party is advised to conduct its own review of 2016 import data with regard to the possible application of GSP CNLs. Please see the notice announcing the 2016 GSP Review which was published in the
Federal Highway Administration (FHWA), U.S. Department of Transportation (USDOT).
Notice of proposed MOU and request for comments.
This notice announces that FHWA has received and reviewed a renewal package from the California Department of Transportation (Caltrans) requesting renewed participation in the Surface Transportation Project Delivery Program (Program). This Program allows for FHWA to assign, and States to assume, responsibilities under the National Environmental Policy Act (NEPA), and all or part of FHWA's responsibilities for environmental review, consultation, or other actions required under any Federal environmental law with respect to one or more Federal highway projects within the State. The FHWA has determined the renewal package to be complete, and developed a draft renewal MOU with Caltrans outlining how the State will implement the program with FHWA oversight. The public is invited to comment on Caltrans' request, including its renewal package and the proposed renewal MOU, which includes the proposed assignments and assumptions of environmental review, consultation and other activities.
Please submit comments by December 16, 2016.
To ensure that you do not duplicate your docket submissions, please submit them by only one of the following means:
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For the FHWA: Shawn Oliver by email at:
An electronic copy of this notice may be downloaded from the
Section 327 of title 23, United States Code (23 U.S.C. 327), allows the Secretary of the DOT (Secretary) to assign, and a State to assume, the responsibilities under the National Environmental Policy Act of 1969 (NEPA) (42 U.S.C. 4321
Caltrans entered the Surface Transportation Project Delivery Pilot
On June 22, 2015, after coordination with FHWA, Caltrans submitted the renewal package in accordance with the renewal regulations in 23 CFR 773.115. On December 4, 2015, President Obama signed into law the
Under the proposed renewal MOU, FHWA would assign to the State, through Caltrans, the responsibility for making decisions on the following types of highway projects:
1. All Class I, or environmental impact statement (EIS) projects, both on the State highway system (SHS) and local government projects off the SHS that are funded by FHWA or require FHWA approvals. This assignment does not include the environmental review associated with the development and approval of the Draft EIS, Final EIS, and ROD for the following project: District 1: Eureka/Arcata Corridor Improvement.
2. All Class II, or categorically excluded (CE), projects, both on the SHS and local government projects off the SHS that are funded by FHWA or require FHWA approvals, and that do not qualify for assignment of responsibilities pursuant to the MOU for environmental reviews and decisions for actions qualifying for CEs pursuant to the 23 U.S.C. 326 program.
3. All Class III, or environmental assessment (EA) projects, both on the SHS and local government projects off the SHS that are funded by FHWA or require FHWA approvals with the exception of the following projects: District 5: Highway 1 Congestion Management-Santa Cruz HOV Lanes and District 9: Inyo-395 Olancha to Cartago 4 Lane.
4. Projects funded by other Federal agencies [or projects without any Federal funding] of any Class that also include funding by FHWA or require FHWA approvals. For these projects, Caltrans would not assume the NEPA responsibilities of other Federal agencies.
Excluded from assignment are highway projects authorized under 23 U.S.C. 202 and 203, highway projects under 23 U.S.C. 204 unless the project will be designed and constructed by Caltrans, projects that cross State boundaries, and projects that cross or are adjacent to international boundaries.
The assignment also would give Caltrans the responsibility to conduct the following environmental review, consultation, and other related activities:
The proposed renewal MOU would allow Caltrans to continue to act in the place of FHWA in carrying out the environmental review-related functions described above, except with respect to government-to-government consultations with federally recognized Indian tribes. The FHWA will retain responsibility for conducting formal government-to-government consultation with federally recognized Indian tribes, which is required under some of the listed laws and executive orders. Caltrans will continue to handle routine consultations with the tribes and understands that a tribe has the right to direct consultation with FHWA upon request. Caltrans also may assist FHWA with formal consultations, with consent of a tribe, but FHWA remains responsible for the consultation. The FHWA and Caltrans have received requests for formal consultations with several tribes regarding the proposed renewal of the MOU and currently are engaged in ongoing consultations. Caltrans also will not assume FHWA's responsibilities for conformity determinations required under Section 176 of the Clean Air Act (42 U.S.C. 7506) or any responsibility under 23 U.S.C. 134 or 135, or under 49 U.S.C. 5303 or 5304.
The MOU content reflects Caltrans' desire to continue its participation in the Program without any changes (that is, no new responsibilities were requested). The FHWA and Caltrans have agreed to modify some of the provisions in the MOU to: Establish the monitoring process required by the permanent Program; accommodate changes specified in Section 1308 of the FAST Act; clarify, the role of the Department of Justice and FHWA in settlements and appeals; and to make the renewed MOU notice and review time frames consistent with other States in this program. The FHWA and Caltrans have also agreed on a process to address a possible temporary lapse in the State's statutory consent to Federal court jurisdiction and waiver of sovereign immunity waiver. If the State does not provide consent to Federal court jurisdiction and waive sovereign immunity by December 31, 2016, this MOU will be suspended and Caltrans will not be able to make any NEPA decisions or implement any of the environmental review responsibilities assigned under the MOU. The FHWA and Caltrans propose a temporary suspension not to exceed 90 days to provide time for the State to address the deficiency. In the event that the State does not take the necessary action and Caltrans does not provide adequate certification within the time period provided, the State's participation in the Program will be terminated.
A copy of the proposed renewal MOU and renewal package may be viewed on the DOT DMS Docket, as described above, or may be obtained by contacting FHWA or the State at the addresses provided above. A copy also may be viewed on Caltrans' Web site at
23 U.S.C. 327; 42 U.S.C. 4331, 4332; 23 CFR 771.117; 40 CFR 1507.3, 1508.4.
Federal Highway Administration (FHWA), U.S. Department of Transportation (DOT).
Notice of proposed MOU and request for comments.
This notice announces that FHWA has received and reviewed an application from the Utah Department of Transportation (UDOT) requesting participation in the Surface Transportation Project Delivery Program (Program). This Program allows for FHWA to assign, and States to assume, responsibilities under the National Environmental Policy Act of 1969 (NEPA), and all or part of FHWA's responsibilities for environmental review, consultation, or other actions required under any Federal environmental law with respect to one or more Federal highway projects within the State. The FHWA has determined the application to be complete and developed a draft MOU with UDOT outlining how the State would implement the program with FHWA oversight. The FHWA invites the public to comment on UDOT's request, including its application and the proposed MOU, which includes the proposed assignments and assumptions of environmental review, consultation, and other activities.
Please submit comments by December 16, 2016.
To ensure that you do not duplicate your docket submissions, please submit them by only one of the following means:
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Edward Woolford, Right of Way and Environmental Manager, Federal Highway Administration Utah Division, 2520 West 4700 South, Suite 9A, Salt Lake City, UT 84129, 7:00 a.m.-4:30 p.m. (MT), (801) 955-3524,
Brandon Weston, Director, Environmental Services, Utah Department of Transportation, 4501 South 2700 West, P.O. Box 148450, Salt Lake City, UT 84114, 8:00 a.m.-5:00 p.m. (MT), (801) 965-4603,
An electronic copy of this notice may be downloaded from the
Section 327 of title 23, United States Code (23 U.S.C. 327), allows the Secretary of the U.S. Department of Transportation (Secretary) to assign, and a State to assume, responsibility for all or part of FHWA's responsibilities for environmental review, consultation, or other actions required under any Federal environmental law with respect to one or more Federal-aid highway projects within the State pursuant to the National Environmental Policy Act of 1969 (42 U.S.C. 4321
Under the proposed MOU, FHWA would assign to the State, through UDOT, the responsibility for making decisions on the following types of highway projects:
1. Highway projects within the State of Utah that are proposed to be funded with title 23 funds or otherwise require FHWA approval, and that require preparation of an environmental impact statement (EIS) or environmental assessment (EA) with the exception of the following EIS project: West Davis Corridor EIS—This project is in UDOT Region 1 in western Davis and Weber Counties.
2. Highway projects qualifying for categorical exclusions (CE) within the State of Utah that are proposed to be funded with title 23 funds or that otherwise require FHWA approvals, and that do not qualify for assignment of responsibilities pursuant to the MOU for environmental review assignment for projects qualifying for CEs (23 U.S.C. 326 MOU) executed on June 30, 2014.
3. Projects funded by other Federal agencies (or projects without any Federal funding) that also require FHWA approvals. For these projects, UDOT would not assume the NEPA responsibilities of other Federal agencies. However, UDOT may use or adopt other Federal agencies' NEPA analyses consistent with 40 CFR parts 1500-1508, and DOT and FHWA regulations, policies, and guidance.
4. Excluded from assignment are highway projects authorized under 23 U.S.C. 202, 203, and 204 unless the project will be designed and/or constructed by UDOT, projects that cross State boundaries, and projects that cross or are adjacent to international boundaries.
The assignment also would give the State the responsibility to conduct the following environmental review, consultation, and other related activities for project delivery:
The MOU would allow UDOT to act in the place of FHWA in carrying out the environmental review-related functions described above, except with respect to government-to-government consultations with federally recognized Indian tribes. The FHWA will retain responsibility for conducting formal government-to-government consultation with federally recognized Indian tribes, which is required under some of the listed laws and executive orders. The UDOT will continue to handle routine consultations with the tribes and understands that a tribe has the right to direct consultation with the FHWA upon request. The UDOT also may assist FHWA with formal consultations, with consent of a tribe, but FHWA remains responsible for the consultation.
The UDOT also will not assume FHWA's responsibilities for conformity determinations required under Section 176 of the CAA (42 U.S.C. 7506), or any responsibility under 23 U.S.C. 134 or 135, or under 49 U.S.C. 5303 or 5304.
A copy of the proposed MOU may be viewed on the DOT DMS Docket, as described above, or may be obtained by contacting FHWA or the State at the addresses provided above. A copy also may be viewed on UDOT's Web site at:
The FHWA Utah Division, in consultation with FHWA Headquarters, will consider the comments submitted when making its decision on the proposed MOU revision. Any final MOU approved by FHWA may include changes based on comments and consultations relating to the proposed MOU and will be made publicly available.
23 U.S.C. 327; 42 U.S.C. 4331, 4332; 23 CFR 771.101-139; 23 CFR 773.109; and 40 CFR 1507.3.
Federal Highway Administration (FHWA), DOT.
Notice and request for comment.
Section 1422 of the Fixing America's Surface Transportation (FAST) Act directs the Administrator of the Federal Highway Administration (FHWA) to commission the Transportation Research Board of the National Academy of Sciences to conduct a study on the performance of bridges that received funding under the Innovative Bridge Research and Construction program in meeting the goals of that program. Section 1422 also directs the Administrator of FHWA to provide an opportunity for public comment on the study proposal before commissioning the study. This notice provides the study proposal and the opportunity for public comment.
Comments must be received on or before December 16, 2016.
Mail or hand deliver comments to Docket Management Facility: U.S. Department of Transportation, 1200 New Jersey Avenue SE., Room W12-140, Washington, DC 20590. You may also submit comments electronically at
Mr. Derek Constable, Office of Bridges and Structures, (202) 366-4606, or via email at
An electronic copy of this notice may be downloaded from the specific docket page at
As directed by FAST Act Section 1422, FHWA will commission the Transportation Research Board to conduct a study on the performance of bridges funded by the Innovative Bridge Research and Construction (IBRC) program as provided under section 503(b) of Title 23, United States Code, and in effect on the day before the date of enactment of the Safe, Accountable, Flexible, Efficient Transportation Equity Act: A Legacy for Users (SAFETEA-LU). The IBRC program was originated by the Transportation Equity Act for the 21st Century (TEA-21) with the purpose of demonstrating the application of innovative material technology in the construction of bridges and other structures. Seven goals were identified in TEA-21. SAFETEA-LU continued the program, but amended the program name, purpose, and goals. The program was then discontinued with the passage of the Moving Ahead for Progress in the 21st Century (MAP-21) Act. The FAST Act directs FHWA to commission the Transportation Research Board to conduct a study on the performance of bridges that received funding under the IBRC program. The IBRC program provided funding to help defray costs on more than 400 projects.
The study will include an analysis of the performance of bridges that received funding under the IBRC program in meeting the program goals;
(A) The development of new, cost-effective innovative material highway bridge applications;
(B) the reduction of maintenance costs and lifecycle costs of bridges, including the costs of new construction, replacement, or rehabilitation of deficient bridges;
(C) the development of construction techniques to increase safety and reduce construction time and traffic congestion;
(D) the development of engineering design criteria for innovative products and materials for use in highway bridges and structures;
(E) the development of cost-effective and innovative techniques to separate vehicle and pedestrian traffic from railroad traffic;
(F) the development of highway bridges and structures that will withstand natural disasters, including alternative processes for the seismic retrofit of bridges; and
(G) the development of new nondestructive bridge evaluation technologies and techniques.
The study also will include an analysis of the utility, compared to conventional materials and technologies, of each of the innovative materials and technologies used in projects for bridges under the program in meeting the needs of the United States in 2015 and in the future for a sustainable and low lifecycle cost transportation system; recommendations to Congress on how the installed and lifecycle costs of bridges could be reduced through the use of innovative materials and technologies, including, as appropriate, any changes in the design and construction of bridges needed to maximize the cost reductions; and a summary of any additional research that may be needed to further evaluate innovative approaches to reducing the installed and lifecycle costs of highway bridges.
The FAST Act requires each State that received funds under the program to provide to the Transportation Research Board any relevant data needed to carry out the study.
The FHWA proposes to focus the study on only the technologies implemented by the IBRC program and will only include bridges that received IBRC program funding. The FHWA's Recommendations to Congress on how to reduce the installed and life cycle costs of bridges will also be based upon the IBRC program study and improvements inspired by the program. In addition, FHWA proposes to focus the study on the effect of the designs, materials, and construction methods on the performance of bridges while they are in service.
The FHWA proposes that the assessment of the performance of bridges while they are in service will use existing information and data that is known or has already been collected by the bridge owners. The FHWA proposes the TRB contact recipients of IBRC funding to provide information and data by interview, survey, and/or release of records. Interviews and surveys may be required to determine which projects to focus the study on and to gather relevant background, cost, and performance information. Records required may include data, documents, and reports associated with design, construction, in-service inspection, maintenance, evaluation, monitoring, and other relevant phases or activities.
Interested parties are invited to provide comment on this study proposal.
Sec. 1422, Pub. L. 114-94, 129 Stat. 1312; 49 CFR 1.85.
Federal Railroad Administration (FRA), U.S. Department of Transportation (DOT).
Notice of availability and request for comments.
This document provides the public with notice that Amtrak submitted via FRA's Secure Information Repository a letter dated September 14, 2016, requesting FRA approval of its PTCSP Revision 4.0, dated August 2016, for Amtrak's Advanced Civil Speed Enforcement System II (ACSES II).
FRA will consider comments received by December 16, 2016 before taking final action on the PTCSP. FRA may consider comments received after that date if practicable.
All comments concerning this proceeding should identify Docket Number 2010-0029 and may be submitted by any of the following methods:
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Dr. Mark Hartong, Senior Scientific Technical Advisor, at (202) 493-1332, or
In its PTCSP, Amtrak asserts that the ACSES II system it is implementing is designed as a vital overlay positive train control (PTC) system as defined in 49 CFR 236.1015(e)(2). The PTCSP describes Amtrak's ACSES II implementation and the associated ACSES II safety processes, safety analyses, and test, validation, and verification processes used during the development of ACSES II. The PTCSP also contains Amtrak's operational and support requirements and procedures.
Amtrak's PTCSP and the accompanying request for approval and system certification are available for review online at
Interested parties are invited to comment on the PTCSP by submitting written comments or data. During its review of the PTCSP, FRA will consider any comments or data submitted. However, FRA may elect not to respond to any particular comment and, under 49 CFR 236.1009(d)(3), FRA maintains the authority to approve or disapprove the PTCSP at its sole discretion. FRA does not anticipate scheduling a public hearing regarding Amtrak's PTCSP because the circumstances do not appear to warrant a hearing. If any interested party desires an opportunity for oral comment, the party should notify FRA in writing before the end of the comment period and specify the basis for his or her request.
Anyone can search the electronic form of any written communications and comments received into any of our dockets by the name of the individual submitting the comment (or signing the document, if submitted on behalf of an association, business, labor union, etc.). Under 49 CFR 211.3, FRA solicits comments from the public to better inform its decisions. DOT posts these
Federal Railroad Administration (FRA), U.S. Department of Transportation.
Notice and request for comments.
Under the Paperwork Reduction Act of 1995 (PRA) and its implementing regulations, FRA seeks approval of proposed information collection activities listed below. Before submitting this information collection request (ICR) to the Office of Management and Budget (OMB) for approval, FRA is soliciting public comment on specific aspects of the activities, which are identified in this notice.
Comments must be received no later than January 17, 2017.
Submit written comments on any or all of the following proposed activities by mail to either: Mr. Robert Brogan, Information Collection Clearance Officer, Office of Railroad Safety, Regulatory Analysis Division, RRS-21, Federal Railroad Administration, 1200 New Jersey Avenue SE., Mail Stop 25, Washington, DC 20590; or Ms. Kim Toone, Information Collection Clearance Officer, Office of Information Technology, RAD-20, Federal Railroad Administration, 1200 New Jersey Avenue SE., Mail Stop 35, Washington, DC 20590. Commenters requesting FRA to acknowledge receipt of their respective comments must include a self-addressed stamped postcard stating, “Comments on OMB Control Number 2130-0010,” and should also include the title of the collection of information. Alternatively, comments may be faxed to (202) 493-6216 or (202) 493-6497, or emailed to Mr. Brogan at
Mr. Robert Brogan, Information Collection Clearance Officer, Office of Railroad Safety, Regulatory Analysis Division, RRS-21, Federal Railroad Administration, 1200 New Jersey Avenue SE., Mail Stop 25, Washington, DC 20590 (telephone: (202) 493-6292) or Ms. Kim Toone, Information Collection Clearance Officer, Office of Information Technology, RAD-20, Federal Railroad Administration, 1200 New Jersey Avenue SE., Mail Stop 35, Washington, DC 20590 (telephone: (202) 493-6132). (These telephone numbers are not toll free.)
The PRA, 44 U.S.C. 3501-3520, and its implementing regulations, 5 CFR part 1320, require Federal agencies to provide 60-days' notice to the public to allow comment on information collection activities before seeking OMB approval to implement them.
FRA believes that soliciting public comment will promote its efforts to reduce the administrative and paperwork burdens associated with the collection of information that Federal regulations mandate. In summary, FRA reasons that comments received will advance three objectives: (1) Reduce reporting burdens; (2) ensure that it organizes information collection requirements in a “user-friendly” format to improve the use of such information; and (3) accurately assess the resources expended to retrieve and produce information requested.
Below is a brief summary of currently approved information collection activities that FRA will submit for clearance by OMB as required under the PRA:
44 U.S.C. 3501-3520.
Pursuant to Section 10(a)(2) of the Federal Advisory Committee Act (Pub. L. 92-463; 5 U.S.C. App. I), notice is hereby given of a meeting of the Advisory Board of the Saint Lawrence Seaway Development Corporation (SLSDC). The meeting will be held from 2 p.m. to 4 p.m.(EDT) on Wednesday, December 14, 2016 via conference call at the SLSDC's Policy Headquarters, 55 M Street SE., Suite 930, Washington, DC 20003. The agenda for this meeting will be as follows: Opening Remarks; Consideration of Minutes of Past Meeting; Quarterly Report; Old and New Business; Closing Discussion; Adjournment.
Attendance at the meeting is open to the interested public but limited to the space available. With the approval of the Administrator, members of the public may present oral statements at the meeting. Persons wishing further information should contact, not later than Friday, December 9, 2016, Wayne Williams, Acting Chief of Staff, Saint Lawrence Seaway Development Corporation, 1200 New Jersey Avenue SE., Washington, DC 20590; 202-366-0091.
Any member of the public may present a written statement to the Advisory Board at any time.
Office of the Comptroller of the Currency, Treasury (OCC).
Notice and request for comment.
The OCC, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to comment on a revision to this information collection, as required by the Paperwork Reduction Act of 1995 (PRA). An agency may not conduct or sponsor, and a respondent is not required to respond to, an information collection unless it displays a currently valid Office of Management and Budget (OMB) control number. Currently, the OCC is soliciting comment concerning a revision to a regulatory reporting requirement for national banks and federal savings associations titled, “Company-Run Annual Stress Test Reporting Template and Documentation for Covered Institutions With Total Consolidated Assets of $50 Billion or More under the Dodd-Frank Wall Street Reform and Consumer Protection Act.”
Comments must be received by January 17, 2017.
Because paper mail in the Washington, DC area and at the OCC is subject to delay, commenters are encouraged to submit comments by email, if possible. Comments may be sent to: Legislative and Regulatory Activities Division, Office of the Comptroller of the Currency, Attention: 1557-0319, 400 7th Street SW., Suite 3E-218, Mail Stop 9W-11, Washington, DC 20219. In addition, comments may be sent by fax to (571) 465-4326 or by electronic mail to
All comments received, including attachments and other supporting materials, are part of the public record and subject to public disclosure. Do not include any information in your comment or supporting materials that you consider confidential or inappropriate for public disclosure.
Shaquita Merritt, OCC Clearance Officer, (202) 649-5490 or, for persons who are deaf or hard of hearing, TTY, (202) 649-5597, Legislative and Regulatory Activities Division, Office of the Comptroller of the Currency, 400 7th St. SW., Washington, DC 20219. In addition, copies of the templates referenced in this notice can be found on the OCC's Web site under News and Issuances (
The OCC is requesting comment on the following revision to an approved information collection:
In 2012, the OCC first implemented the reporting templates referenced in the final rule.
The OCC intends to use the data collected to assess the reasonableness of the stress test results of covered institutions and to provide forward-looking information to the OCC regarding a covered institution's capital adequacy. The OCC also may use the results of the stress tests to determine whether additional analytical techniques and exercises could be appropriate to identify, measure, and monitor risks at the covered institution. The stress test results are expected to support ongoing improvement in a covered institution's stress testing practices with respect to its internal assessments of capital adequacy and overall capital planning.
The OCC recognizes that many covered institutions with total consolidated assets of $50 billion or more are required to submit reports using reporting form FR Y-14A.
The OCC also recognizes that the Board has proposed to modify its Capital Plan and Stress Testing rule which included modified reporting requirements for bank holding companies (BHCs) categorized by the Board as large and noncomplex firms.
In addition to the changes that parallel the Board's proposed changes to the FR Y-14A, the OCC is also proposing to implement a new supplemental schedule to collect certain items not included in the Board's FR Y-14A.
The proposed revisions to the DFAST-14A reporting templates consist of the following:
• Adding line items to the Regulatory Capital Instruments schedule.
• Updating the Summary schedule to collect items related to the supplementary leverage ratio.
• Removing and adding sub-schedules to the Operational Risk schedule.
• Creating a new supplemental schedule to collect certain items not included in the Board's FR Y-14A.
• Requiring a bank-specific scenario. Covered institutions would be required to submit bank-specific baseline and stress scenarios.
• Requiring the assumption of largest counterparty default. The largest trading covered institutions that also submit the Global Market Shock scenario would be required to assume the default of their largest counterparty in the supervisory severely adverse and adverse scenarios.
Covered institutions would be required to submit bank-specific baseline and bank-specific stress scenarios and associated projections for the 2017 annual stress testing submission. While supervisory scenarios provide a homogeneous scenario and a consistent market-wide view of the condition of the banking sector, these prescribed scenarios may not fully capture all of the risks that may be associated with a particular institution. The proposed revisions would require covered institutions to provide bank-specific baseline and bank-specific stress scenarios.
The OCC recognizes that the Board requires BHCs to submit BHC-specific baseline and stress scenarios and projections. Where OCC covered institutions also submit BHC-specific scenarios, the OCC would require that bank-specific scenarios would be consistent with the BHC-specific scenarios.
Covered institutions that currently complete the Global Market Shock would also be required to complete the Largest Counterparty Default component. This is currently required by the Board, and the OCC would adopt a similar requirement to enhance consistency and reduce regulatory burden.
The proposed revisions include a new supplemental schedule that would collect additional information not otherwise included in the FR Y-14A. This schedule would collect, among other information, additional data on auto lending, commercial exposures, and non-U.S. exposures. The schedule would also collect information relevant to the calculation of the Supplementary Leverage Ratio.
The other proposed revisions to the DFAST-14A consist of clarifying instructions, adding and removing schedules, adding, deleting, and modifying existing data items, and altering the as-of dates. These proposed changes would increase consistency between the DFAST-14A and the FR Y-14A and Call Report.
The proposed revision includes multiple line item changes intended to promote consistency with the FR Y-14A and ensure the collection of accurate information.
Covered institutions would be required to estimate their supplementary leverage ratio for the planning horizon beginning on January 1, 2018. The OCC proposes adding two items to the Summary Schedule: Supplementary Leverage Ratio Exposure (SLR Exposure) and Supplementary Leverage Ratio (the SLR). The SLR would be a derived field.
In addition, to collect more precise information regarding deferred tax assets (DTAs), the OCC proposes modifying one existing item on the Capital—DFAST worksheet of the Summary schedule as-of December 31, 2016. The OCC proposes changing existing item 112 on the Capital—DFAST worksheet of the Summary schedule, “Deferred tax assets arising from temporary differences that could not be realized through net operating loss carrybacks, net of DTLs, but before related valuation allowances,” to “Deferred tax assets arising from temporary differences, net of DTLs.” A covered institution in a net deferred tax liability (DTL) position would report this item as a negative number. This modification would provide more specific information about the components of the “DTAs arising from temporary differences that could not be realized through net operating loss carrybacks, net of related valuation allowances and net of DTLs” subject to the common equity tier 1 capital deduction threshold.
The proposed revisions would also remove certain items that pertained to the capital regulations in place before the adoption of the Basel III final rule.
The OCC proposes adding the item “Other counterparty losses” to the counterparty worksheet of the Summary schedule.
The proposed revisions would remove and add sub-schedules to the Operational Risk Schedule to ensure the collection of accurate information. The OCC proposes adding two sub-schedules and modifying the supporting documentation requirements for this schedule effective with the reports as-of December 31, 2016. First, new sub-schedule Material Risk Identification would collect information on a firm's material operational risks included in loss projections based on their risk management framework. Second, new sub-schedule Operational Risk Scenarios would collect a covered institution's operational risk scenarios included in the BHC Baseline and BHC Stress projections, a fundamental element of the framework.
The Operational Risk Historical Capital sub-schedule would be removed from the reporting template.
(a) Whether the collection of information is necessary for the proper performance of the functions of the OCC, including whether the information has practical utility;
(b) The accuracy of the OCC's estimate of the burden of the collection of information;
(c) Ways to enhance the quality, utility, and clarity of the information to be collected;
(d) Ways to minimize the burden of the collection on respondents, including through the use of automated collection techniques or other forms of information technology; and
(e) Estimates of capital or start-up costs and costs of operation, maintenance, and purchase of services to provide information.
Notice is hereby given that on November 9, 2016, the Office of the Comptroller of the Currency (OCC) approved the application of Community Savings, Caldwell, Ohio, to convert to the stock form of organization. Copies of the application are available on the OCC Web site at the FOIA Reading Room (
By the Office of the Comptroller of the Currency.
The Department of the Treasury will submit the following information collection requests to the Office of Management and Budget (OMB) for review and clearance in accordance with the Paperwork Reduction Act of 1995, Public Law 104-13, on or after the date of publication of this notice.
Comments should be received on or before December 16, 2016 to be assured of consideration.
Send comments regarding the burden estimates, or any other aspect of the information collections, including suggestions for reducing the burden, to (1) Office of Information and Regulatory Affairs, Office of Management and Budget, Attention: Desk Officer for Treasury, New Executive Office Building, Room 10235, Washington, DC 20503, or email at
Copies of the submissions may be obtained by emailing
Notification of Citizens Coinage Advisory Committee November 17, 2016, public meeting.
Pursuant to United States Code, Title 31, section 5135(b)(8)(C), the United States Mint announces the Citizens Coinage Advisory Committee (CCAC) public meeting scheduled for November 17, 2016.
Interested persons should call the CCAC HOTLINE at (202) 354-7502 for the latest update on meeting time and room location.
In accordance with 31 U.S.C. 5135, the CCAC:
Advises the Secretary of the Treasury on any theme or design proposals relating to circulating coinage, bullion coinage, Congressional Gold Medals, and national and other medals.
Advises the Secretary of the Treasury with regard to the events, persons, or places to be commemorated by the issuance of commemorative coins in each of the five calendar years succeeding the year in which a commemorative coin designation is made.
Makes recommendations with respect to the mintage level for any commemorative coin recommended.
Betty Birdsong, Acting United States Mint Liaison to the CCAC; 801 9th Street NW.; Washington, DC 20220; or call 202-354-7770.
Any member of the public interested in submitting matters for the CCAC's consideration is invited to submit them by fax to the following number: 202-756-6525.
31 U.S.C. 5135(b)(8)(C).
Veterans Benefits Administration, Department of Veterans Affairs.
Notice.
The Veterans Benefits Administration (VBA), Department of Veterans Affairs (VA), is announcing an opportunity for public comment on the proposed collection of certain information by the agency. Under the Paperwork Reduction Act (PRA) of 1995, Federal agencies are required to publish notice in the
VA Forms 21-0960A-1, 21-0960B-1, and 21-0960C-1 are used to gather necessary information from a claimant's treating physician regarding the results of medical examinations.
Written comments and recommendations on the proposed collection of information should be received on or before January 17, 2017.
Submit written comments on the collection of information through Federal Docket Management System (FDMS) at
Nancy J. Kessinger at (202) 632-8924 or FAX (202) 632-8925.
Under the PRA of 1995 (Pub. L. 104-13; 44 U.S.C. 3501-21), Federal agencies must obtain approval from the Office of Management and Budget (OMB) for each collection of information they conduct or sponsor. This request for comment is being made pursuant to Section 3506(c)(2)(A) of the PRA.
With respect to the following collection of information, VBA invites comments on: (1) Whether the proposed collection of information is necessary for the proper performance of VBA's functions, including whether the information will have practical utility; (2) the accuracy of VBA's estimate of the burden of the proposed collection of information; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) ways to minimize the burden of the collection of information on respondents, including through the use of automated collection techniques or the use of other forms of information technology.
By direction of the Secretary.
The Department of Veterans Affairs (VA) gives notice under the Federal Advisory Committee Act, 5 U.S.C. App. 2, that a meeting of the Veterans' Advisory Committee on Rehabilitation (VACOR) will be held on December 12th-13th, 2016 in Conference Room 542 at the Department of Veterans Affairs, 1800 G Street NW., Washington, DC 20006. The meeting will begin at 9:00 a.m. (EST) and adjourn at 5:00 p.m. (EST) each day. The meeting is open to the public.
The purpose of the Committee is to provide advice to the Secretary on the rehabilitation needs of Veterans with disabilities and on the administration of VA's rehabilitation programs.
During the meeting, Committee members will be provided updated briefings on various VA programs designed to enhance the rehabilitative potential of recently-discharged Veterans. Members will also begin consideration of potential recommendations to be included in the Committee's next annual report.
Although no time will be allocated for receiving oral presentations from the public, members of the public may submit written statements for review by the Committee to Anthony Estelle, Designated Federal Officer, Veterans Benefits Administration (28), 810 Vermont Avenue NW., Washington, DC 20420, or via email at
Office of the Secretary, HUD.
Final rule.
This final rule implements in HUD's regulations the requirements of the 2013 reauthorization of the Violence Against Women Act (VAWA), which applies for all victims of domestic violence, dating violence, sexual assault, and stalking, regardless of sex, gender identity, or sexual orientation, and which must be applied consistent with all nondiscrimination and fair housing requirements. The 2013 reauthorization (VAWA 2013) expands housing protections to HUD programs beyond HUD's public housing program and HUD's tenant-based and project-based Section 8 programs (collectively, the Section 8 programs) that were covered by the 2005 reauthorization of the Violence Against Women Act (VAWA 2005). Additionally, the 2013 law provides enhanced protections and options for victims of domestic violence, dating violence, sexual assault, and stalking. Specifically, this rule amends HUD's generally applicable regulations, HUD's regulations for the public housing and Section 8 programs that already pertain to VAWA, and the regulations of programs newly covered by VAWA 2013.
In addition to this final rule, HUD is publishing a notice titled the Notice of Occupancy Rights under the Violence Against Women Act (Notice of Occupancy Rights) that certain housing providers must give to tenants and applicants to ensure they are aware of their rights under VAWA and these implementing regulations, a model emergency transfer plan that may be used by housing providers to develop their own emergency transfer plans, a model emergency transfer request form that housing providers could provide to tenants requesting an emergency transfer under these regulations, and a new certification form for documenting incidents of domestic violence, dating violence, sexual assault, and stalking that must be used by housing providers.
This rule reflects the statutory changes made by VAWA 2013, as well as HUD's recognition of the importance of providing housing protections and rights to victims of domestic violence, dating violence, sexual assault, and stalking. By increasing opportunities for all individuals to live in safe housing, this will reduce the risk of homelessness and further HUD's mission of utilizing housing to improve quality of life.
For information about: HUD's Public Housing program, contact Monica Shepherd, Director Public Housing Management and Occupancy Division, Office of Public and Indian Housing, Room 4204, telephone number 202-402-5687; HUD's Housing Choice Voucher program and Project-Based Voucher, contact Becky Primeaux, Director, Housing Voucher Management and Operations Division, Office of Public and Indian Housing, Room 4216, telephone number 202-402-6050; HUD's Multifamily Housing programs, contact Yvette M. Viviani, Director, Housing Assistance Policy Division, Office of Housing, Room 6138, telephone number 202-708-3000; HUD's HOME Investment Partnerships program, contact Virginia Sardone, Director, Office of Affordable Housing Programs, Office of Community Planning and Development, Room 7164, telephone number 202-708-2684; HUD's Housing Opportunities for Persons With AIDS (HOPWA) program, contact Rita Flegel, Director, Office of HIV/AIDS Housing, Office of Community Planning and Development, Room 7248, telephone number 202-402-5374; and HUD's Homeless programs, contact Norman Suchar, Director, Office of Special Needs Assistance, Office of Community Planning and Development, telephone number 202-708-4300. The address for all offices is the Department of Housing and Urban Development, 451 7th Street SW., Washington, DC 20410. The telephone numbers listed above are not toll-free numbers. Persons with hearing or speech impairments may access these numbers through TTY by calling the Federal Relay Service, toll-free, at 800-877-8339.
This rule implements the HUD housing provisions in VAWA 2013, which are found in Title VI of the statute. (See Pub. L. 113-4, 127 Stat. 54, approved March 7, 2013, at 127 Stat. 101). VAWA 2005 (Pub. L. 109-162, 119 Stat. 2959, approved January 5, 2006) applied VAWA protections to certain HUD programs by amending the authorizing statutes for HUD's public housing and section 8 programs to provide protections for victims of domestic violence, dating violence, and stalking. VAWA 2013 removes these amendments from the public housing and section 8 authorizing statutes, and in its place provides stand-alone VAWA protections that apply to these programs, as well as additional HUD programs, and also to victims of sexual assault. In addition, VAWA 2013 expands protections for victims of domestic violence, dating violence, sexual assault, and stalking by amending the definition of domestic violence to include violence committed by intimate partners of victims, and by providing that tenants cannot be denied assistance because an affiliated individual of theirs is or was a victim of domestic violence, dating violence, sexual assault, or stalking (collectively VAWA crimes). The new law also expands remedies for victims of domestic violence, dating violence, sexual assault, and stalking by requiring covered housing providers to have emergency transfer plans, and providing that if housing providers allow for bifurcation of a lease, then tenants should have a reasonable time to establish eligibility for assistance under a VAWA-covered program or to find new housing when an assisted household has to be divided as a result of the violence or abuse covered by VAWA.
VAWA 2013 provides protections for both applicants for and tenants of assistance under a VAWA-covered housing program. VAWA 2013 covers applicants, as well as tenants, in the statute's nondiscrimination and notification provisions. However, the emergency transfer and bifurcation provisions of the rule are applicable solely to tenants. The statutory provisions of VAWA that require a notice of occupancy rights, an emergency transfer plan, and allow for the possibility of bifurcation of a lease, support that it is a rental housing situation that is the focus of the VAWA protections. However, as described in this final rule, the core statutory protections of VAWA that prohibit
This rule better enables housing providers to comply with the mandates of VAWA 2013, and it reflects Federal policies that recognize that all individuals should be able to live in their homes without fear of violence. The implementation of VAWA protections in HUD programs increases opportunities for all individuals to live in safe housing and reduces the risk of homelessness for individuals who might otherwise be evicted, be denied housing assistance, or flee their homes.
Major provisions of this rule include:
• Specifying “sexual assault” as a crime covered by VAWA in HUD-covered programs.
• Establishing a definition for “affiliated individual” based on the statutory definition and that is usable and workable for HUD-covered programs.
• Applying VAWA protections to all covered HUD programs as well as the Housing Trust Fund, which was not statutorily listed as a covered program.
• Ensuring that existing tenants, as well as new tenants, of all HUD-covered programs receive notification of their rights under VAWA and HUD's VAWA regulations.
• Establishing reasonable time periods during which a tenant who is a victim of domestic violence, dating violence, sexual assault, or stalking may establish eligibility to remain in housing, where the tenant's household is divided due to a VAWA crime, and where the tenant was not the member of the household that previously established eligibility for assistance.
• Establishing that housing providers may, but are not required to, request certain documentation from tenants seeking emergency transfers under VAWA.
• Providing for a six-month transition period to complete an emergency transfer plan and provide emergency transfers, when requested, under the plan.
• Revising and establishing new program-specific regulations for implementing VAWA protections in a manner that is workable for each HUD-covered program.
Please refer to section II of this preamble, entitled “This Final Rule” for a more detailed discussion of all the changes made to HUD's existing regulations by this rule. In developing this rule, HUD identified outdated terminology in its regulations (for example, the use of the term “alcohol abuser” in part 982). HUD will be issuing a future rule to update and correct such terms.
The benefits of HUD's rule include codifying in regulation the protections that VAWA 2013 provides applicants to and tenants of HUD programs covered by VAWA; strengthening the rights of victims of domestic violence, dating violence, sexual assault, or stalking in HUD-covered programs, including notification and confidentiality rights; and possibly minimizing the loss of housing by such victims through the bifurcation of lease provision and emergency transfer provisions. With respect to rental housing, VAWA was enacted to bring housing stability to victims of domestic violence, dating violence, sexual assault or stalking. It was determined that legislation was needed to require protections for such victims because housing providers often responded to VAWA crimes occurring in one of their rental units or on their property by evicting the tenant regardless of whether the tenant was a victim of domestic violence, dating violence, sexual assault, or stalking, and refusing to rent to such victims on the basis that violence would erupt in the victim's unit or on a housing provider's property if the individual was accepted as a tenant. To ensure that housing providers administering HUD assistance did not respond to domestic violence, dating violence, or stalking by denying or terminating assistance, VAWA 2005 brought HUD's public housing and Section 8 programs under the statute's purview, and VAWA 2013 covered the overwhelming majority of HUD programs providing rental assistance.
The costs of the regulations are primarily paperwork costs. These are the costs of providing notice to applicants and tenants of their occupancy rights under VAWA, the preparation of an emergency transfer plan, and documenting an incident or incidents of domestic violence, dating violence, sexual assault, and stalking. The costs, however, are minimized by the fact that VAWA 2013 requires HUD to prepare the notice of occupancy rights to be distributed to applicants and tenants; to prepare the certification form that serves as a means of documenting the incident or incidents of domestic violence, dating violence, sexual assault, and stalking; and to prepare a model emergency transfer plan that guides the entities and individuals administering the rental assistance provided by HUD in developing their own plans. In addition, costs to covered housing providers will be minimized because HUD will translate the notice of occupancy rights and certification form into the most popularly spoken languages in the United States, and HUD has prepared a model transfer request form that housing providers and tenants requesting emergency transfer may use. There may also be costs with respect to a tenant claiming the protections of VAWA and a covered housing provider responding to such incident, although these costs will vary depending on the incidence of claims in a given year and the nature and complexity of the situation.
On March 7, 2013, President Obama signed into law VAWA 2013 (Pub. L. 113-4, 127 Stat. 54). VAWA 2013 reauthorizes and amends VAWA 1994 (Title IV, sec. 40001-40703 of Pub. L. 103-322), which was previously reauthorized by VAWA 2000 (Pub. L. 106-386) and VAWA 2005 (Pub. L. 109-162, approved January 5, 2006, with technical corrections made by Pub. L. 109-271, approved August 12, 2006).
The VAWA 2005 reauthorization brought HUD's public housing program and HUD's Section 8 programs under coverage of VAWA by amending the authorizing statutes for those programs, sections 6 and 8 of the United States Housing Act of 1937 (the 1937 Act) (42 U.S.C. 1437
Title VI of VAWA 2013, “Safe Homes for Victims of Domestic Violence, Dating Violence, Sexual Assault, and Stalking,” contains the provisions that are applicable to HUD programs. Specifically, section 601 of VAWA 2013 removes VAWA protections from the 1937 Act and adds a new chapter to Subtitle N of VAWA 1994 (42 U.S.C. 14043e
On August 6, 2013, at 78 FR 47717, HUD published a
Many of the comments submitted in response to the August 6, 2013, notice asked HUD to advise program participants that certain VAWA protections are in effect without the necessity of rulemaking. In response to these comments, HUD offices administering HUD-covered programs reached out to participants in their programs to advise them that the core statutory protections of VAWA—not denying or terminating assistance to, or evicting an individual solely on the basis that an individual is or has been a victim of domestic violence, dating violence, stalking, or sexual assault—were effective upon enactment and do not require notice and comment rulemaking for implementing these protections and that they should proceed to provide the basic VAWA protections.
On April 1, 2015, HUD published its proposed rule that provided the amendments to HUD's existing regulations that HUD determined necessary to fully implement VAWA 2013. The public comment period on the April 1, 2015, rule closed on June 1, 2015. HUD received 94 comments, including duplicate mass mailings, resulting in 68 distinct comments. The comments were submitted by housing authorities, other housing providers, organizations that represent or provide services to specific groups of housing providers, organizations that advocate for victims and survivors of domestic and sexual violence, state coalitions against domestic violence, other advocacy and not-for-profit organizations and associations, state and local government agencies, a tribal organization, and numerous unaffiliated individuals. All public comments can be viewed at:
Most commenters expressed support for the rule, with different questions and comments about specific provisions. There were many comments regarding emergency transfers, lease bifurcation, and documentation requirements, as well as comments on eligibility for and limitations on VAWA protections, the roles and responsibilities of different housing providers under different HUD programs, the notice of occupancy rights, implementation and enforcement of the rule, confidentiality, and other issues. In addition, there were a number of program-specific comments. HUD responds to issues raised by the public comments in Section II.B. of this preamble.
This final rule reflects the Federal government's recognition that all people have a right to live their lives safely. On September 9, 2014, in Presidential Proclamation 9164—Twentieth Anniversary of the Violence Against Women Act, and on September 30, 2014, in Presidential Proclamation 9181—National Domestic Violence Awareness Month, 2014, President Obama discussed the “basic human right to be free from violence and abuse.” The implementation of the policies laid out in this rule will help to enforce this basic human right.
HUD notes that, in addition to utilizing housing protections in VAWA, victims of domestic violence, dating violence, sexual assault, and stalking, and those assisting them, may wish to consider other available protections and assistance. On the Federal level, for example, the U.S. Department of Justice (DOJ) administers programs that provide funding for victims of crime, including victims covered by VAWA. The Office for Victims of Crime (OVC), part of DOJ, administers the Crime Victims Fund, which provides direct reimbursement to crime victims for financial losses from crimes including medical costs, mental health counseling, and lost wages or loss of support. This provides reimbursement for victims during a time when they may be facing financial constraints. The Crime Victims Fund may also be used to fund transitional housing and shelter for victims of domestic violence, dating violence, sexual assault, or stalking who need the transitional housing or shelter because they were a victim of one of these crimes, and to fund relocation expenses for those who need to move because they were a victims of domestic violence, dating violence, sexual assault, or stalking. OVC also provides grants to public and non-profit organizations for essential services to victims of crime, including emergency shelter, and the Office of Violence Against Women (OVW), also part of DOJ, administers 24 grant programs where funds are provided to states, territories, local government, non-profit organizations, and community organizations for various targeted persons. Information about the Crime Victims Fund is available at:
Further, victims of domestic violence, dating violence, sexual assault, and stalking should be aware that State and local laws may provide greater protections than Federal law, and local victim service providers and social service agencies may have further information regarding this.
After review and consideration of the public comments and upon HUD's further consideration of VAWA 2013 and the issues raised in the proposed rule, HUD has made certain changes in this final rule. The following highlights the substantive changes made by HUD in this final rule from the proposed rule.
The final rule:
• Clarifies that, consistent with HUD's nondiscrimination and equal opportunity requirements, victims of domestic violence, dating violence, sexual assault, and stalking cannot be discriminated against on the basis of any protected characteristics (including race, color, religion, sex, disability, familial status, national origin, or age), and HUD programs must also be operated consistently with HUD's Equal Access Rule (HUD-assisted and HUD-insured housing must be made available to all otherwise eligible individuals and families without regard to actual or perceived sexual orientation, gender identity or marital status). (See § 5.2001(a).)
• Provides that in regulations governing short-term supported housing, emergency shelters, and safe havens, these forms of shelter are subject to the core protections of VAWA that prohibit denial of admission or eviction or termination to an individual solely on the basis that the individual is a victim of domestic violence, dating violence, or stalking, or sexual assault. (See §§ 574.604(a)(2), 576.409(f), and 578.99(j)(9).)
• Revises the definition of “affiliated individual” to incorporate situations where an individual has guardianship over another individual who is not a child. (See § 5.2003.)
• Revises the definition of “domestic violence” to incorporate a definition of “spouse or intimate partner” rather than cross-reference to another definition of the term, and to eliminate the cross-reference to “crime of violence,” a more restricting term. (See § 5.2003.)
• Provides that existing tenants in HUD-covered programs receive HUD's Notice of Occupancy Rights and accompanying certification form no later than one year after this rule takes effect, during the annual recertification or lease renewal process, if applicable, or through other means if there will be no annual recertification or lease renewal process for a tenant. (See § 5.2005(a)(2)(iv).)
• Retains the provision of HUD's regulations implementing VAWA 2005, for those HUD programs covered by VAWA 2005, which states that the HUD-required lease, lease addendum, or tenancy addendum must include a description of the specific protections afforded to the victims of VAWA crimes. (See § 5.2005(a)(4).)
• Clarifies that applicants may not be denied assistance and tenants may not have assistance terminated under a covered housing program for factors resulting from the fact that the applicant or tenant is or has been a victim of a VAWA crime. (See § 5.2005(b)(1).)
• Emphasizes that victims of sexual assault may qualify for an emergency transfer if they either reasonably believe there is a threat of imminent harm from further violence if they remain in their dwelling unit, or the sexual assault occurred on the premises during the 90-calendar-day period preceding the date of the request for transfer. (See § 5.2005(e)(2)(ii).)
• Provides that emergency transfer plans must detail the measure of any priority given to tenants who qualify for an emergency transfer under VAWA in relation to other categories of individuals seeking transfers or placement on waiting lists. (See § 5.2005(e)(3).)
• Provides that emergency transfer plans must allow for a tenant to transfer to a new unit when a safe unit is immediately available and the tenant would not have to apply in order to occupy the new unit (§ 5.2005(e)(5)).
• Provides that emergency transfer plans must describe policies for assisting tenants to make emergency transfers when a safe unit is not immediately available, both for situations where a tenant would not have to apply in order to occupy the new unit, and where the tenant would have to apply in order to occupy the new unit. (See § 5.2005(e)(6), § 5.2005(e)(7), and § 5.2005(e)(8)).
• Provides that the emergency transfer plans must describe policies for assisting tenants who have tenant-based rental assistance to make emergency moves with that assistance. (§ 5.2005(e)(9)).
• Adds a provision that emergency transfer plans may require documentation, as long as tenants can establish eligibility for an emergency transfer by submitting a written certification to their housing provider, and no other documentation is required for tenants who have established that they are victims of domestic violence, dating violence, sexual assault, or stalking to verify eligibility for a transfer. (See § 5.2005(e)(10).)
• Requires housing providers to make emergency transfer plans available upon request, and to make them publicly available whenever feasible. (See § 5.2005(e)(11).)
• Provides for a six-month transition period to complete an emergency transfer plan and provide emergency transfers, when requested, under such plan. (See § 5.2005(e) or applicable program regulations)
• Emphasizes that tenants and applicants may choose which of the forms of documentation listed in the rule to give to housing providers to document the occurrence of a VAWA crime. (See § 5.2007(b)(1).)
• Provides that in cases of conflicting evidence, tenants and applicants who may need to submit third-party documentation to document occurrence of a VAWA crime have 30 calendar days to submit the third-party documentation. (See § 5.2007(b)(2).)
• Provides that if a covered housing provider bifurcates a lease under VAWA, any remaining tenants who had not already established eligibility for assistance must be given either the maximum time permitted by statute, or, if there are no statutory prohibitions, at least 90 calendar days from the date of bifurcation of the lease or until expiration of the lease, depending on the covered housing program, to establish eligibility for a covered housing program, or find alternative housing (See § 5.2009(b)(2).)
• Provides that if a family in a HOME-assisted rental unit separates under § 5.2009(a), the remaining tenant(s) will retain the unit. (See § 92.359(d)(1).)
• Provides that if a family receiving HOME tenant-based rental assistance separates under § 5.2009(a), the tenant(s) who are not removed will retain the HOME tenant-based rental assistance, and the participating jurisdiction must determine whether a tenant who was removed from the unit will receive HOME tenant-based rental assistance. (See § 92.359(d)(2).)
• Establishes VAWA regulations for the Housing Trust Fund, based on the regulations for the HOME program. (See 24 CFR part 93.)
• Emphasizes that VAWA protections apply to eviction actions for tenants in
• Clarifies in the HOPWA regulations that the grantee or project sponsor is responsible for ensuring that the owner or manager of a facility assisted under HOPWA develops and uses a VAWA lease addendum. (See part 574.)
• Clarifies who is the covered housing provider for HUD's multifamily Section 8 project-based programs and the Section 202 and Section 811 programs, by providing that the covered housing provider is the owner for the Section 8 Housing Assistance Payments Programs for New Construction (part 880), for Section 515 Rural Rental Housing Projects (part 884), and for Special Allocations (part 886), as well as for the Section 202 and Section 811 programs (part 891) and that PHAs and owners each have certain responsibilities as covered housing providers for the Section 8 Moderate Rehabilitation Program (part 882), and the Section 8 State Housing Agencies Program for State Housing Agencies (part 883).
• Updates various section 8 and public housing VAWA 2005 regulations to broadly state that VAWA protections apply, so that all tenants and applicants, and not only those determined to be victims of VAWA crimes, receive statutorily required notification of their VAWA rights. (See parts 880, 882, 883, 884, 886, 891, 960, 966, and 982.)
• Clarifies that VAWA protections and requirements apply to mixed finance developments. (See § 905.100(g).)
• Clarifies that public housing agencies (PHAs), like other covered providers, may establish preferences for victims of dating violence, sexual assault, and stalking, in addition to domestic violence, consistent with their statutory authority. (See §§ 960.206(b)(4), 982.207(b)(4).)
• Clarifies that for the Section 8 Housing Choice Voucher and Project-Based Voucher programs, the PHA is the housing provider responsible for complying with VAWA emergency transfer provisions. (See §§ 982.53(e), 983.3(b).)
As noted earlier in this preamble, the majority of the commenters expressed support for the rule, but they also presented questions and comments about specific provisions of the rule. The primary provisions of the rule on which commenters posted comments pertained to emergency transfers, lease bifurcation, documentation requirements, eligibility for and limitations on VAWA protections, the roles and responsibilities of different housing providers under different HUD programs, the notice of occupancy rights, implementation and enforcement of the rule, and confidentiality requirements. The following presents the significant issues raised by the commenters and HUD's response to the comments.
A commenter stated that HUD's final rule's definitions of domestic violence, dating violence, sexual assault or stalking must be sufficiently clear so as not to cause survivors to be punished for ancillary crimes as a result of the abuse they have suffered or cause survivors to be blamed for the abuse. Commenters said some survivors have been evicted because they “invited” the perpetrator into the home and subsequently received an eviction notice under Crime Free Drug Free policies
Some commenters asked that HUD revise § 5.2005(b) to state that an applicant may not be denied assistance, or a tenant have assistance terminated or be evicted “on the basis or as a result of the fact that the applicant or tenant is or has been a victim of domestic violence . . .” in order to clarify that victims are protected from the results of economic abuse, such as poor credit.
In addition to revising § 5.2005(b), HUD will provide guidance for covered housing providers to aid how they may determine whether factors that might otherwise serve as a basis for denial or termination of assistance or eviction have directly resulted from the fact that an applicant or tenant is or has been a victim of domestic violence, dating violence, sexual assault, or stalking. As commenters noted, HUD has already provided in its Public Housing Occupancy Guidebook that PHAs should inquire about the circumstances that may have contributed to negative reporting to determine whether that negative reporting was a consequence of domestic violence.
Commenters suggested that HUD add economic abuse to the scope of VAWA protections in § 5.2001 and to the list of protected victims throughout § 5.2005. A commenter said that, should HUD determine not to revise the text of the regulations to address economic abuse, HUD should nevertheless clarify that VAWA covers economic abuse.
Commenters also suggested that HUD establish a notification and certification process to ensure that victims of economic abuse receive VAWA protections. Commenters said a victim of economic abuse could supply a certification regarding such abuse when applying for a HUD program. Commenters said that whenever an individual's ability to participate in a HUD program is compromised due to economic factors, the individual must be notified that VAWA protections may apply.
As described in the proposed rule, VAWA 2013 removed the statutory definition of stalking that HUD incorporated into the rule implementing VAWA 2005, but maintained a universal definition of stalking that applies throughout VAWA, as codified in 42 U.S.C. 13925(a)(30). As a result, this rule replaces the statutorily removed definition of stalking with the universal definition of stalking in VAWA. HUD disagrees with the commenters' assertion that this change reduces VAWA protections by eliminating harassment and intimidation considerations. The previous definition of “stalking” included specific actions (including harassment and intimidation) that either placed a person in reasonable fear of death or serious bodily injury or caused substantial emotional harm. The universal definition of “stalking,” provided in this final rule, involves any course of conduct directed at a specific person that would cause a reasonable person to fear for their own safety or the safety of others, or suffer substantial emotional distress.
Another commenter stated that the proposed rule advised that if an unreported member of the household is the victim of domestic violence, dating violence, sexual assault, or stalking, the tenant may not be evicted because of such action as long as the tenant was not the perpetrator. The commenter stated that, in the proposed rule, HUD agreed with comments that VAWA protections should not extend to individuals violating program regulations, such as housing unauthorized occupants. The commenter stated that HUD's statement seems contradictory because HUD is in effect extending VAWA protections to a tenant who violates program regulations by allowing a person who is not authorized to reside in the unit. The commenter asked HUD to advise how to respond if a housing provider learns of the existence of an unreported member of the household in violation of program regulations, based solely on a tenant's reporting of a VAWA incident against the unreported member. The commenter said HUD's rule does not establish a clear nexus for the prohibition against denial or termination of assistance “on the basis” that an applicant or tenant is or has been a domestic violence victim.
Other commenters stated that the preamble to the proposed rule created confusion when it stated that affiliated individuals do not receive VAWA protections if they are not on the lease and that the protections of VAWA are directed to tenants. Commenters stated that specific protections, however, may extend to affiliated individuals or be limited to tenants or lawful occupants. In support of this statement, the commenters stated that no individual may be denied housing in a covered program based on the individual's status as a survivor, but the right to bifurcate the lease and preserve the subsidy is limited to tenants or lawful occupants. Commenters asked HUD to correct language in the preamble to the proposed rule that they stated incorrectly construed the protections of VAWA as applying only to those named on the lease, and added that whether an individual is a “tenant” or a “lawful occupant” is a question of State law on which HUD should not take a position, as this could conflict with State law. Commenters further stated that, as part of the dynamics of an abusive relationship, a survivor will often not be listed as a tenant on the lease but may be a lawful occupant. Commenters concluded their comments stating that, to limit protections to “tenants” or to individuals specifically named on the lease, without regard for how a lawful occupant might be characterized under State or local laws, undermines the very purpose of VAWA.
A live-in aide or a guest could be an affiliated individual of a tenant, and if that aide or guest is a victim of domestic violence, dating violence, sexual assault, or stalking, the tenant with whom the affiliated individual is associated cannot be evicted or have assistance terminated on the basis that the affiliated individual was a victim of a VAWA crime. Moreover, where a live-in aide is a victim of domestic violence, dating violence, sexual assault, or stalking, and the tenant seeks to maintain the services of the live-in aide, the housing provider cannot require that the live-in aide be removed from the household on the grounds of being a victim of abuse covered by VAWA. The live-in aide resides in the unit as a reasonable accommodation for the tenant with a disability. Indeed, to require removal of the live-in aide solely because the aide is a victim of abuse covered by VAWA likely would violate Section 504 of the Rehabilitation Act, the Fair Housing Act, and the Americans with Disabilities Act, as applicable, which require housing providers to permit such reasonable accommodations. In addition, if a tenant requests and qualifies for an emergency transfer on the grounds that the live-in aide is a victim of domestic violence, dating violence, sexual assault, or stalking, the tenant's entire household, which includes the live-in aide, can be transferred.
Section 5.2005(d)(2) of this final rule states that covered housing providers can evict or terminate assistance to a tenant for any violation not premised on an act of domestic violence. However, if an individual, who is a victim of domestic violence, has an unreported member residing in the individual's household and the individual is afraid of asking the unreported member to leave because of the individual's domestic violence experience, then terminating the individual's tenancy because of the unreported household member would be “premised on an act of domestic violence.” Therefore, depending on the situation, a tenant who violates program regulations by housing a person not authorized to reside in the unit could be covered by VAWA's anti-discrimination provisions, and eligible for remedies provided under VAWA.
As discussed above, HUD interprets the term “on the basis” in VAWA 2013's prohibitions against denying admission to, denying assistance under, terminating a tenant from participation in, or evicting a tenant from housing “on the basis” that the applicant or tenant is or has been a victim of domestic violence, dating violence, sexual assault, or stalking, to include factors directly resulting from the domestic violence, dating violence, sexual assault, or stalking.
With respect to the comments about applying the VAWA protections to survivors of domestic violence, dating violence, sexual assault, and stalking whether they are named on the lease or not, HUD notes that the term “lawful occupant” is not defined in VAWA 2013 and appears in the statute four times in the following contexts: (i) In the definition of “affiliated individual” as a type of “affiliated individual”; (ii) in the documentation section of the statute as those who could be evicted if they commit violations of the lease if the applicant or tenant does not provide requested documentation; (iii) in the bifurcation section, as those who could be evicted for engaging in criminal activity directly relating to domestic violence, dating violence, sexual assault, or stalking; and (iv) as those who might not be negatively affected if a lease is bifurcated. Other than stating that a housing provider may, at the provider's discretion, bifurcate a lease
All housing providers should be aware of other Federal, State and local laws that may provide similar or more extensive rights to victims of domestic violence, dating violence, sexual assault, and stalking. For example, properties funded with Low-Income Housing Credits (LIHTCs) are also subject to VAWA requirements, and housing providers should look to the regulatory agency responsible for LIHTCs—the Department of Treasury—for how to implement VAWA protections in those properties.
Housing providers should also be aware more generally of other Federal fair housing and civil rights laws that may be applicable, including, but not limited to, the Fair Housing Act, Section 504 of the Rehabilitation Act, the Americans with Disabilities Act, and Title VI of the Civil Rights Act. For example, housing providers might violate the Fair Housing Act under a discriminatory effects theory if they have an unjustified policy of evicting victims of domestic violence, as such a policy might disproportionately harm females or individuals that have another protected characteristic.
In contrast to this comment, another commenter stated that HUD's final rule should make clear that a tenant or family can be entitled to VAWA protection on more than one occasion and cannot be subjected to additional conditions that adversely affect their tenancy because they have invoked VAWA protections. The commenter said it has dealt with covered housing providers that decided to impose additional requirements on tenants who sought VAWA protections, such as requiring tenants to obtain protective orders or call the police, conditions they do not impose on other tenants, including those who are victims of other crimes (non-VAWA crimes), and this violates VAWA.
Allowing housing providers to apply a different occupancy standard to survivors of domestic violence, dating violence, sexual assault, and stalking than that applied to victims of other crimes violates the intent of VAWA, which provides that housing providers cannot discriminate against survivors and victims of a VAWA crime. HUD also agrees that survivors do not have to contact authorities, such as police, or initiate legal proceedings against an abuser or perpetrator in order to qualify for VAWA protections. The statute has no such requirements and instead allows survivors to provide self-certification about the VAWA incident(s).
However, as mentioned in the proposed rule, there have been no new Section 202 direct loans since 1990. All Section 202 direct loan projects, as with projects under other HUD programs, that received any type of direct assistance prior to VAWA 2013 are not subject to new statutory requirements on HUD programs unless there is some ongoing contractual agreement with HUD or the statute specifically speaks to retroactive application for existing projects. Therefore, unless the Section
A commenter also said that the proposed regulations in 24 CFR 574.604(a)(2) and 578.99(j) are too broad, and where rental assistance is provided and there is a written agreement or a lease, VAWA should apply to short-term supported housing and McKinney-Vento Safe Havens. Another commenter asked for guidance that clearly allows senior housing providers the option to extend VAWA protections to victim residents, even if their program type was not specifically included in the statute.
Tenants in units under a HUD-covered program maintain their VAWA protections where their units are converted to coverage under a new HUD program. The conversion does not eliminate their VAWA protections. With respect to RAD, tenants in converted units continue to be covered by VAWA's protections provided under HUD's Section 8 Project-Based Voucher program or Project-Based Rental Assistance Program.
Choice Neighborhoods is a development tool that uses grant funds to develop housing to address struggling neighborhoods with distressed public or HUD-assisted housing. The assistance may come from public housing, RAD or HOME funds. Therefore, tenants residing in units developed with Choice funds receive VAWA protections under the relevant rental subsidy programs where assistance comes from a HUD-covered housing program.
The Rent Supplement program provides continued assistance on active or newly expired original term contracts. Though the program is no longer active, families continue to be supported until each Rent Supplement contract expires. For the VAWA protections to apply, tenants need to be residing in a project that receives Rent Supplement payments and is also subject to VAWA, such a section 221(d)(3)/(d)(5) project or section 236 project. Once a Rent Supplement contract expires, families may receive tenant protection vouchers and are then under the Housing Choice Voucher (HCV) program (
Tenants in public housing that received funding under the HOPE VI program would continue to have the same VAWA rights as other public housing residents.
To ensure tenants in mixed-finance projects receive VAWA protections, this final rule adds a new provision at 24 CFR 905.100(g) that provides that PHAs must apply the VAWA protections under part 5 for mixed finance developments.
This rule maintains the provisions in §§ 574.604(a)(2) and 578.99(j) that state the requirements in 24 CFR part 5, subpart L, that are specific to tenants or those who are applying to become tenants (such as the notice of occupancy rights for tenants and applicants, and bifurcation of leases and emergency transfer plans for tenants) do not apply to short-term supported housing and McKinney-Vento Safe Havens, as the regulations for tenants could not be applied in those contexts. However, in response to commenters' concerns, the regulations in this final rule explicitly provide that safe havens and short-term supported housing are subject to the core protections of VAWA (the prohibitions against denying admission or terminating assistance on the basis that the individual is or has been a victim of domestic violence, dating violence, stalking or sexual assault).
This rule clarifies, in the HOPWA regulations at 24 CFR 574.604(a)(2), and the regulations for the Continuum of Care (CoC) program at 578.99(j), that, although the requirements in 24 CFR part 5, subpart L, do not apply to short-term supported housing or safe havens, no individual may be denied admission to or removed from the short-term supported housing or safe haven on the basis or as a direct result of the fact that the individual is or has been a victim of domestic violence, dating violence, sexual assault, or stalking, if the individual otherwise qualifies for admission or occupancy.
Commenters stated that the plain language of VAWA does not exclude shelters, and said that “applicable assistance,” which cannot be denied or terminated pursuant to VAWA, does not necessarily have to be tied to rental assistance. Commenters said admission and termination policies and practices at homeless shelters can often exclude survivors of domestic violence, dating violence, sexual assault and stalking, and victims report having to recount the violence and report being subject to a higher standard of admission and conditions of stay than other participants, such as producing orders of protection. Commenters said these victims are also denied admission if they are considered “unsafe” for the program, and in family shelters, domestic violence survivors are sometimes terminated from the program along with the perpetrator if they are abused on the property.
Commenters said Continuums of Care often choose homeless shelter programs as the main entry point into coordinated assessment, and if shelters' exclusionary practices continue without VAWA's protections, survivors may be excluded from access not only to emergency shelter, but also to other resources and housing. Commenters said such practices undermine HUD's efforts to end homelessness to exclude shelters from VAWA protection because, in many CoCs, they will be the entry point through which victims experiencing homelessness access tenant-based rental assistance, transitional housing and other HUD-funded homelessness programs.
However, as HUD stated in its proposed rule, the regulatory requirements in 24 CFR part 5, including the notice of occupancy rights, apply to assistance for rental housing, which generally involves a tenant, a landlord (the individual or entity that owns and/or leases rental units) and a lease specifying the occupancy rights and obligations of the tenant. This is because, as explained elsewhere in this rule, those VAWA protections are directed to rental housing.
HUD emphasizes in this final rule that victims cannot be discriminated against on the basis of any protected characteristic, including race, color, national origin, religion, sex, familial
Under both VAWA 2013 and HUD's regulations, a tenant may not be denied tenancy or occupancy rights solely on the basis of criminal activity directly relating to domestic violence, dating violence, sexual assault, or stalking if that tenant or an affiliated individual of the tenant is the victim or threatened victim of such domestic violence, dating violence, sexual assault or stalking. In essence, the inclusion of affiliated individual is to add a further protection for tenants by providing that a VAWA crime committed against an affiliated individual, an individual without VAWA protections, is not a basis for denying or terminating assistance to the tenant. HUD declines to change or limit the definition of “affiliated individual” to exclude “any individual.” The statute provides that the term includes any individual “living in the household of the person who is eligible for VAWA protections.”
Commenters also said HUD's proposed rule identifies the PHA as the entity responsible for providing the reasonable time to establish eligibility for assistance following bifurcation of a lease for HUD's multifamily Section 8 project-based programs, but § 5.2009(b) of the rule defines the time that a tenant has to establish eligibility for assistance and does not give a covered housing provider flexibility in that regard. A commenter said that, it is the owner, not the PHA that establishes eligibility, and therefore, it should be the owner, not the PHA, to provide the reasonable time to establish eligibility.
A commenter stated that the definition of “covered housing provider” in 24 CFR parts 880, 882, 884, 886, 891, 982, and 983 was proposed, in the April 1, 2015, proposed rule to be the same as in 24 CFR part 883. The commenter encouraged HUD to review the definition of covered housing provider in the context of how each of the programs is actually administered and reevaluated whether the definition is appropriate. A commenter recommended that any activity that requires an interaction with a tenant should be assigned to the owner or its manager; and a State housing agency should be responsible only for monitoring the delivery of appropriate notices and that correct policies are in place and being followed. The commenter stated that, if model forms for use by an owner are required, the State housing agency, if not HUD, could provide them.
Other commenters stated that, for the Moderate Rehabilitation Single Room Occupancy (SRO) program, the proposed rule stated that the owner is the covered housing provider, but it is unclear why the PHA is not also considered the covered housing provider since the PHA has duties in administering the program. The commenters stated that it is unclear which entity is responsible for adopting, administering, and facilitating the emergency transfer plan, which entity is responsible for maintaining confidentiality and lease bifurcation, and which entity is responsible for providing the VAWA housing rights notice and certification form. Commenters stated that confidentiality must be maintained by the entity that obtains the information about the victim, and when a lease bifurcation occurs, the owner and the PHA must coordinate to provide a reasonable time for the tenant to establish eligibility for the same covered program or another covered program.
Another commenter said that the State recipient should be the conduit and responsible party for implementation. The commenter said that, because CoCs operate distinctly across a State and PHAs have considerable local control, it is important that the implementation of VAWA be consistent and equally applied to survivors, regardless of where they may reside in a State, and the State recipient could serve in an ombudsman-type role in order to ensure that all organizations and individuals understand their roles and obligations. The commenter said State recipients should specifically be tasked with developing model notices, forms, and the emergency transfer plans in collaboration with the statewide domestic violence and sexual assault coalition(s), which then can be adopted and implemented by local CoCs. Commenters recommended that HUD's final rule clarify the duties of housing providers under Emergency Solutions Grants (ESG) and CoC programs with regard to enacting VAWA protections.
Commenters further stated that the proposed rule did not address how the various VAWA obligations will be delegated or shared among the various parties—recipient, subrecipient, owner or landlord—that may be responsible for ensuring the delivery of VAWA obligations and protections, particularly regarding evictions and establishing a reasonable time for an individual to establish eligibility or find alternative housing.
A commenter stated that proposed § 960.102 provides the definition of “covered housing provider” for public housing and states that it is the PHA, but this is not appropriate or effective in those situations where another entity owns the public housing units and the PHA manages the units, for example, in mixed finance units, HOPE VI units, or Choice Neighborhoods developments. For the public housing units that are not owned by the PHA, the commenter said the responsibilities to comply with court orders, request documentation, maintain confidentiality of documentation, determine the appropriateness of lease bifurcation, and reasonable times to provide an individual to establish program eligibility, must apply to both the PHA and the owner. The commenter said the owner, who has the lease with the tenant, must be responsible for providing the notice and certification form, determining whether to evict or terminate for reasons other than those protected by VAWA, or if there is an “actual or imminent threat,” and to assist victims to remain in their unit and bear the cost of transfer, where permissible. In addition, the commenter said the PHA must adopt an emergency transfer plan with which the owner must comply, and owners should be restricted from taking any steps toward evicting or terminating a tenant until the PHA notifies the owner that the documentation from a claimed victim has not been received or conflicting claims of victimization have been resolved.
Commenters recommended that HUD amend §§ 960.102, 960.103(d), 960.203(c)(4), 966.4(e) to acknowledge situations where the public housing units are owned by a private owner and are managed by a PHA. The commenters further recommended that HUD state generally that the entity taking the action (
For HUD's multifamily Section 8 project-based programs in 24 CFR parts 880, 884, and 886, and for the Section
For the multifamily Section 8 programs under parts 882 and 883, however, the PHA (which would be a state agency for part 883) administers the programs. Therefore, it is the PHA that has primary oversight responsibilities under VAWA, and it is the PHA that has the contract with the owner of the housing (not HUD) and consequently the PHA must set the housing policy to be followed and must ensure that the owner and all of the owners with whom the PHA has a contract comply with the VAWA regulations and those VAWA policies that the PHA has been given discretion to determine. For these reasons, in these programs HUD maintains the provision in the proposed rule that identifies the PHA as the covered housing provider responsible for providing the notice of occupancy rights under VAWA and the certification form to tenants and applicants. In this final rule, HUD further clarifies that the PHA is responsible for providing the notice and form to owners to give to tenants and applicants. In addition, for parts 882 and 883, including the Moderate Rehabilitation SRO program, HUD further clarifies in this final rule that both the PHA and the owner are responsible for ensuring an emergency transfer plan is in place for the covered housing, but it is the owner that has responsibility for implementing the emergency transfer plan when an emergency arises, since the PHA does not have a direct relationship with the tenant. Since both PHAs and owners are covered housing providers for these programs, both PHAs and owners must adhere to this rule's basic provisions regarding denial or termination of assistance or occupancy rights and the construction of lease terms in § 5.2005(b) and (c), and the limitations of VAWA protection in § 5.2005(d) also apply to both PHAs and owners. Similarly, the documentation and confidentiality provisions in § 5.2007 of this rule also apply to both owners and PHAs.
HUD agrees with commenters that the provisions in the proposed rule that the PHA is responsible for providing the reasonable time to establish eligibility for assistance following bifurcation of a lease in the definition of covered housing provider in parts 880, 882, 883, 884, 886, and 891, as well as in § 982.53(e) and § 983.3, was unclear and unnecessary. HUD removes these provisions in this final rule. In each of these programs, this final rule clarifies that the owner is the covered housing provider that may choose to bifurcate a lease and, if the owner chooses to do so, must follow any applicable regulations relating to lease bifurcation.
For the regulations in part 982 (the housing choice voucher program) and in part 983 (the project-based voucher program), this final rule clarifies that it is the PHA that is the covered housing provider responsible for complying with the emergency transfer plan requirements in § 5.2005(e). Unlike the case with HUD's multifamily Section 8 project-based programs, PHAs do have a direct relationship with tenants in the housing choice voucher and project-based voucher program, and it is appropriate for tenants to contact the PHA about emergency transfers under VAWA, as they would contact the PHA about other matters related to administration of their housing assistance. In addition, given the relationship between the tenant and the PHA in these programs, this rule maintains the provisions in the proposed rule that the PHA is responsible for providing the notice of occupancy rights and the certification form. As is the case for HUD's multifamily Section 8 programs under parts 882 and 883, for the housing choice voucher and project-based voucher programs, both PHAs and owners are covered housing providers who must adhere to this rule's basic provisions regarding denial or termination of assistance or occupancy rights and the construction of lease terms in § 5.2005(b) and (c), and the limitations of VAWA protection in § 5.2005(d) also apply to both PHAs and owners. Similarly, the documentation and confidentiality provisions in § 5.2007 of this rule also apply to both owners and PHAs.
For the CoC and ESG programs, the proposed rule and this final rule lay out the responsibilities of recipients, subrecipients, and housing owners in § 576.407(g) (for ESG) and § 578.99(j) (for CoC).
For mixed finance units and public housing developments that received public housing assistance under the Choice Neighborhoods and HOPE VI programs' NOFAs, the PHA is the covered housing provider because these units are generally administered in the same manner as other public housing units.
For FHA multifamily programs, HUD revises the definition of covered housing provider under this rule in § 200.38(b) to remove the provision that HUD will provide guidance as to who the covered housing provider is. HUD clarifies in this rule that the covered housing provider is generally the mortgagor for FHA multifamily programs covered by VAWA. However, where an existing mortgagor/owner sells the project to a new entity “subject to” the mortgage, in which case the new entity would own the project but not be the mortgagor under the mortgage, then the owner would be the covered housing provider.
Further, HUD has revised the regulations for HUD's multifamily Section 8 project-based programs in 24 CFR parts 880, 884, and 886 to specify that the owner is the covered housing provider. HUD has also revised the regulations for the Section 202 and Section 811 programs in part 891 to clarify that the owner is the covered housing provider.
HUD has revised the definition of covered housing provider in 24 CFR part 883, as well as the definition of covered housing provider in § 882.102 for Section 8 Moderate Rehabilitation Programs, other than the Single Room Occupancy Program for Homeless Individuals, to clarify that the PHA is the covered housing provider responsible for providing the notice of occupancy rights and certification form under VAWA, and that the PHA may provide this notice and form to owners, and charge an owner with distribution to tenants. HUD also revises the regulations in these parts to eliminate the provision that the PHA is the covered housing provider responsible for providing the reasonable time to establish eligibility for assistance following bifurcation of a lease, and to clarify that the PHA and owner are both responsible for ensuring that an emergency transfer plan is in place, and it is the owner that is responsible for implementing the emergency transfer plan when an emergency occurs. HUD retains the provision in § 882.802 that the owner is the covered housing
In addition, HUD has revised regulations for the Housing Choice Voucher program, at § 982.53(e) and the project-based voucher program, at § 983.3, to remove the provision that the PHA is the covered housing provider responsible for providing the reasonable time to establish eligibility for assistance following bifurcation of a lease. HUD also revises the regulations in these parts to clarify that the PHA is responsible for complying with this rule's provisions on emergency transfer plans.
Another commenter stated that, if PHAs are collaborating with ESG and CoC program grantees, PHAs would still be subject to the lease requirements currently imposed by HUD with respect to the public housing and Section 8 programs, and if HUD seeks to impose different lease requirements on these programs when overlaid with ESG and CoC programs, HUD will need to provide additional guidance to the PHAs.
Where housing is covered under multiple HUD programs, such as under the HOME and Section 8 Project-Based programs, the responsible housing provider under each program will provide the required notice of occupancy rights and certification form, and tenants may request emergency transfers or lease bifurcations under either program. Where there is a conflict between different program regulations, § 5.2001(b)(2) of HUD's VAWA regulation applies. As discussed earlier in this preamble, § 5.2001(b)(2) states that, where assistance is provided under more than one covered housing program and the VAWA protections or remedies under those programs conflict, the individual seeking the VAWA protections or remedies may choose to use the protections or remedies under any or all of those programs, as long as the protections or remedies would be feasible and permissible under each of the program statutes.
A commenter stated that the definition of “domestic violence” should not be tied to 18 U.S.C. 16 because that definition excludes a great deal of domestic violence crimes under State and tribal laws, as well as common law definitions of “battery.” The commenter stated that with the proposed rule's definition, there will be a great deal of uncertainty as to whether a particular conviction actually constitutes a crime under 18 U.S.C. 16.
Another commenter said that the matter of domestic violence has specific legal implications in most jurisdictions. The commenter stated that the proposed rule includes felony or misdemeanor crimes of violence in the definition, which implies formal charges filed by a prosecutor. The commenter said that in the locality in which the commenter resides, all cases initially thought to meet the test for domestic violence are further reviewed by prosecutors and are often re-classified to different charges.
On further consideration, HUD determined that a cross-reference to 18 U.S.C. 2266(7) may be confusing, as the term “domestic violence” includes felony or misdemeanor crimes of violence committed by a current or former spouse or intimate partner of the victim, or others, and 18 U.S.C. 2266(7) defines “intimate partner” as the victim and not the abuser. As a result, the cross reference reads as if domestic violence is a crime of violence committed by the victim, rather than the perpetrator.
A commenter stated that third-party documentation may help to eliminate transfer of the same situation to a new location, and that this documentation is necessary for the housing provider to document the case in detail. The commenters said that documentation other than self-certification is necessary to verify the need for an emergency transfer, as the form's provisions regarding penalties for fraud would be difficult to enforce, and some victims may attempt to use an incident of domestic violence to obtain a superior housing unit or break their current lease, even if this is unrelated to a VAWA incident. A commenter pointed to a State law allowing a tenant who is the victim of domestic violence to legally break a lease, but only with some type of third-party documentation. Commenters said requiring additional documentation is logical because housing providers will take a monetary and temporal loss for transfers. Other commenters stated that statements from legal, medical, psychological or social service providers stating their belief that a transfer will have a strong probability of reducing a recurrence of the violence should be required for emergency transfers. Another commenter stated that landlords should request a detailed statement from the victim, and then interview the victims after the transfer and obtain a written statement from regarding whether the violence stopped or the transfer benefited the resident.
HUD understands that tenants seeking emergency transfers may not have already submitted to their housing provider documentation of any occurrence of domestic violence, dating violence, sexual assault, or stalking, and HUD did not intend to indicate that there is an assumption that a tenant seeking an emergency transfer has already been previously determined to be a victim of domestic violence, dating violence, sexual assault, or stalking. HUD clarifies in this final rule that housing providers may require tenants seeking emergency transfers to document an occurrence of domestic violence, dating violence, sexual assault, or stalking, in addition to documenting eligibility for an emergency transfer, consistent with the HUD requirement that individuals certify eligibility in order to establish that the tenant is a victim of domestic violence, dating violence, sexual assault, or stalking, if the individual has not already provided documentation of that occurrence. HUD notes as part of certifying eligibility for VAWA protections an individual may provide self-certification in lieu of any other documentation to document an occurrence of a VAWA-protected incident. Because self-certification can be submitted fairly quickly, submission of a self-certification should not delay any requests for an emergency transfer.
In addition to documentation—which could be self-certification—of the occurrence of domestic violence, dating violence, sexual assault, or stalking, the final rule allows housing providers to require that tenants seeking emergency transfers provide documentation—which could be a written request—that they meet the requirements for a transfer. HUD is allowing housing providers to request this additional documentation because an individual may be a victim of violence covered by VAWA, and yet not meet the requirements for an emergency transfer that are specified in VAWA 2013. Those requirements are that the individual expressly request the transfer and either reasonably believe there is a threat of imminent harm from further violence if the tenant remains in the same dwelling unit that the tenant is currently occupying or, in the case of a tenant who is a victim of sexual assault, the tenant also qualifies for a transfer if the assault occurred on the premises during the 90-calendar-day period preceding the date of request for the transfer.
HUD appreciates commenters' concerns that third-party proof cannot always be easily obtained, that it may not be available to some tenants who qualify for emergency transfers, and the requirement to obtain third-party documentation could delay transfers, resulting in harm to tenants. It is for these reasons that the final rule stipulates that housing providers may not require third-party documentation for an emergency transfer.
As noted above, housing providers may, however, require that tenants submit a written request for an emergency transfer where they certify their need for a transfer. This is a change from the proposed rule. Although the proposed model emergency transfer plan stated that tenants should submit a written request for a transfer, the proposed rule did provide that housing providers may require this request. HUD disagrees with commenter's interpretation of VAWA 2013 that because the statute does not discuss documentation requirements for emergency transfers, HUD may not allow housing providers to require that tenants submit any documentation whatsoever.
HUD also does not agree with some of the arguments that commenters presented in favor of requiring third-party documentation for an emergency transfer. HUD does not believe that a failure to require third-party documentation would result in negating the benefits of a transfer, and leave the tenant in an endangered situation. Rather, strict confidentiality measures to prevent a perpetrator from learning the new location of the transferred tenant would help to reduce the possibility of future violence.
HUD understands that some housing providers expressed concern that there may be tenants who request an emergency transfer for the purpose of obtaining a superior housing unit or to break their current lease. This situation may occur but, for the following reasons, HUD does not agree that this justifies a third-party documentation requirement that could endanger the lives of those tenants who are victims of VAWA crimes and for whom safety and security is a real threat.
First, third-party documentation of a VAWA-protected incident would not necessarily help a housing provider determine whether a victim reasonably believes that the victim is in imminent harm from further violence without a transfer. Second, the housing provider may request that the tenant sign a written request for the transfer that states that the information in the request is accurate, and that submission of false information could jeopardize program eligibility and be the basis for denial of admission, termination of assistance, or eviction. HUD further disagrees with commenters who suggested that landlords should request a detailed statement from, and interview, victims. There are housing providers who may have experience working with victims of domestic violence, dating violence, sexual assault, or stalking, but there are also housing providers who do not. Regardless, under this rule, housing providers will not judge the merits of the claims of victims of domestic violence, dating violence, sexual assault, or stalking. HUD understands that the documentation of homelessness may be important when transferring a tenant, but this does not require third-party documentation of the need for a transfer due to domestic violence, dating violence, sexual assault, or stalking.
HUD agrees with those commenters who said that providers should be permitted to use their discretion to determine whether documentation is needed, and housing providers will not be required to request documentation from those seeking an emergency transfer due to an incident of domestic violence, dating violence, sexual assault, or stalking, just as housing providers are not required to request documentation of the VAWA-related incidence. However, as previously discussed, under this final rule, housing providers will not be allowed to require that tenants requesting an emergency transfer under VAWA submit third-party documentation to qualify for an emergency transfer. HUD understands that many PHAs have high occupancy rates, but notes that transfers are only required where there is a safe and available unit to transfer the tenant to, and, where there is a transfer, the unit from which the tenant is transferring will become available. Further, allowing housing providers to decide for themselves what documentation is sufficient for an emergency transfer could leave them more legally
This final rule also revises § 5.2007(a)(1) to remove the provision that the documentation requirements in the section are not applicable to a request made by the tenant for an emergency transfer. This provision was removed because housing providers may require tenants seeking emergency transfers to document an occurrence of domestic violence, dating violence, sexual assault, or stalking, if they have not done so already, in addition to documenting eligibility for an emergency transfer.
As previously discussed, under this final rule, covered housing providers may require in their emergency transfer plans that victims of domestic violence, dating violence, sexual assault, or stalking submit a written request to their housing provider, where the tenants certify that they meet the requirements for an emergency transfer, in addition to any self-certification or other documentation of an occurrence of domestic violence, dating violence, sexual assault or stalking. This means that if the tenant provides these self-certifications, and the covered housing provider has another safe and available unit for which the victim qualifies, the housing provider must allow the tenant to transfer. If the covered housing provider has a VAWA emergency transfer waiting list, the only documentation that a housing provider could require the tenant to submit in order to be placed on the waiting list is a written emergency transfer request, where the tenant certifies to meeting the requirements for an emergency transfer under VAWA, in addition to any self-certification or other documentation of an occurrence of domestic violence, dating violence, sexual assault or stalking, as described in § 5.2005(e)(6).
Other commenters said costs can be substantial. A commenter said costs also include criminal background and drug tests. Another commenter said it currently employs an entire team dedicated to processing emergency transfers for public housing tenants and HCV participants and, in addition to these personnel costs, the commenter said that it spends approximately $14,000 on preparing each public housing unit for a new occupant, and $200 in administrative costs for each HCV emergency transfer. Commenter said that if the perpetrator is not removed from the apartment before transferring the victim, subsidizing the perpetrator in one apartment and the victim in a second apartment could occur, thereby greatly increasing the transfer costs.
A commenter said that an informal poll of its PHA members finds that unit transfers cost between $500 and $5500, depending on the amount of work that needs to be undertaken upon turnover. The commenter explained that an estimate of $3000-$4000 would include painting, carpet or tile replacement, cleaning costs, lock changes, possible appliance replacement or repair, and shade replacement, and an additional $500 should be added for each additional bedroom.
Another commenter estimated that relocation of a public housing tenant through HCV assistance costs between 5 and 17 staff hours and $50 to $100 in subcontractor fees for inspections. The commenter said that, at best, relocation through the HCV program involves staff time spent issuing a voucher, reviewing the “Request for Tenancy Approval,” inspection and rent reasonableness determination of a new unit, preparation of a new lease and housing assistance payments contract (HAP), and recertification of the family. The commenter added that costs may increase for a PHA due to additional inspections, since an initially chosen unit may not be affordable or appropriate, and the processing of multiple Requests for Tenancy Approval forms. The commenter further stated that, if the perpetrator is a member of the assisted household, the PHA may also be undergoing the process of terminating the perpetrator's individual assistance, which could result in hearing costs and potential legal fees.
A commenter said public housing costs include moving costs and damage caused by the tenant beyond normal wear and tear, an average turnaround time of 8 days during which time the unit is not occupied while it is being made ready for the next family, and an average cost in parts and labor of $215 plus an additional $200 for cleaning. For the HCV program, the commenter said moving costs and damage caused by the tenant and any additional costs to make the unit ready for the next occupant is born by the landlord. The commenter said that HCV staff spend about 8 hours processing moves, and the total cost of their time and the resources expended is about $200.
Another commenter said that if there are damages beyond normal wear and tear, and if the participant fails to pay those costs, landlords must not only incur these costs but face the costs of pursuing collection. This commenter said lost rent on each unit while it is vacant could amount to 60 or 90 days, which could result in the loss of Operating Fund eligibility in the subsequent year for public housing, and in the voucher program, costs include the loss of renewal funding in subsequent years for lost unit months leased (UMLs) and lost fees.
A commenter said that in the past 5 years it has spent over $339,000 on 118 emergency transfers for temporary hotel accommodations as well as moving expenses. Commenter said it has been experiencing a steady annual increase in the number of emergency transfer requests in general and in VAWA specifically.
A commenter said that if the tenant and management agree that the tenant cannot afford transfer costs, services representatives can seek assistance from local resources, or, management could put forth the costs and allow the tenant to repay them under a payment plan. A commenter said departing residents paying costs under a repayment plan is consistent with HUD's policy with respect to other resident-initiated transfers as set forth in the Public Housing Occupancy Guidebook.
Commenters suggested that HUD establish a special fee to ensure that PHAs are able to withstand the financial implications of transfers under VAWA. Others commenters said moving costs should be considered to be permissible program expenses. Commenters said HUD should reimburse covered housing providers for costs associated with these transfers and such requirement should be provided for in the rule and could be established in a PIH notice.
In response to commenters who stated housing providers should not be responsible for costs since this is not a reasonable accommodation covered under Section 504, the issue of whether housing providers must pay for emergency transfers is a separate issue from reasonable accommodation requests under Section 504. Section 504 pertains to providing and paying for structural modifications that may be necessary as a reasonable accommodation for individuals with disabilities.
As noted in the proposed rule, HUD's CoC regulations, in addition to containing regulations that provide for a victim of domestic violence, dating violence, sexual assault, or stalking to retain their tenant-based rental assistance and move to a different CoC geographic area, include reasonable one-time moving costs as eligible supportive services cost. (See 24 CFR 578.53(e)(2).) In addition, under this rule's HOME regulations at § 92.359 (e), HOPWA regulations at § 574.604(f), and CoC regulations at § 578.99(j), leases and occupancy agreements must include a provision that tenants may terminate their leases without penalty if they meet the conditions for an emergency transfer under this rule.
Commenters said HUD should prepare a model emergency transfer request that includes the following information: The eligibility criteria for requesting the emergency transfer, the definition of a “safe and available” unit, a checklist for the required documentation the victim must provide to support the need for such a transfer, including a statement that the tenant reasonably believes he or she is imminently threatened by harm and documentation of the violence and the basis for that belief, and any conditions the tenant must meet to continue to receive VAWA protections, such as not inviting/allowing the perpetrator into
Another commenter said the model request should allow the survivor to assert either an imminent threat of violence or a sexual assault that occurred on the premises within the last 90 days and should reflect the date on which the survivor submitted the request to transfer. Commenter said additional recommendations for inclusion in the model included: Establishment of a grievance plan when transfers are denied, or are granted but unsafe; a provision that survivors incur no costs other than their own expenses to move; a provision that transfer requests be considered mandatory; and a requirement that covered housing programs not penalize survivors who meet the emergency transfer requirements for exercising their rights. A commenter said a model request should include name of the perpetrator, if known, name of the victim(s), names of the family members who would be transferring with the victim, a brief description of why the victim would fear imminent harm or personal threat if made to remain in the unit, and/or self-identification as a sexual assault survivor.
Another commenter said that VAWA 2013 does not require housing providers to adopt the agencies' plans and it may be that providers will write, or will have written, their own plans. Other commenters cited a Senate Committee report from 2012 that said it is the Committee's intent that emergency transfer policies should be tailored to the various types of housing programs covered by the bill, recognizing that housing providers have varying abilities to transfer occupants based on the volume and availability of dwelling units under their control.
A commenter said HUD's model transfer plan must address the obligations for a covered housing provider that receives a request to relocate a survivor to their jurisdiction from another covered housing provider. The commenter said that, at the very least, the model transfer plan should provide guidance for how a covered housing provider should analyze the request and set forth a time frame for responding to the request.
HUD declines, however, to revise the model plan in the other ways suggested by the commenters. This final rule clarifies, in § 5.2005(e), that housing providers may request that participants request emergency transfers in writing, but they are not required to do so, and housing providers may process emergency transfers requests that are not in writing as long as the tenant expressly requests the transfer. As to reference to the size of the housing provider, the model plan already indicates that the housing provider, regardless of size, cannot guarantee that a transfer request will be approved. As HUD noted earlier, HUD is aware of the limited availability of units assisted by HUD under its programs. HUD reiterates that HUD's emergency transfer plan is a model plan and that each housing provider will adopt its own plan. HUD encourages all housing providers to include as much specific information applicable to the transfer as possible, consistent with the requirements of the HUD program in which the housing provider participates.
Another commenter asked which of HUD's housing programs must adopt an emergency transfer plan based on HUD's model plan.
As commenter suggested, HUD has revised its model plan to include a statement that if a tenant reasonably believes a proposed transfer would not be safe, the tenant may request a transfer to a different unit. HUD has also revised its model plan to add a provision stating that tenants who are not in good standing may still request an emergency transfer if they meet the eligibility requirements in this section. As explained elsewhere in this preamble, however, tenants may have to pay certain costs associated with transfers.
Another commenter said HUD should clearly specify how covered housing providers are to balance the interests of applicants and current tenants who may need VAWA protections. Some commenters said HUD should expressly state that housing providers' obligation to help tenants transfer to safe housing supersedes wait list, tenant preference, or prioritization obligations and non-emergency transfers. Commenter said the negative effects of delay in transfers include forced homelessness and seeking emergency shelter, which can affect one's employment and getting children to school.
Other commenters said that HUD should require a preference for victims who have met emergency transfer documentation requirements so that they may move to the top of the waiting list for a transfer to another property under the covered housing provider's control. Other commenters asked that HUD address the implementation of emergency transfers as they relate to other competing tenant preferences such as disability and homelessness.
Commenters said HUD should clarify that housing providers can establish a voluntary preference for the emergency transfer of VAWA-related victims, which could help facilitate a relocation that may require an effective termination at one property, and enable priority move-in at another site that may be separately owned or operated. A commenter asked that HUD articulate how housing providers may adopt a preference for VAWA.
A commenter stated that HUD's model emergency transfer plan does not clarify what the housing provider is required or allowed to do to expedite the transfer process, and requested that HUD expressly state how a PHA and owner should comply with the transfer requirement given the covered providers' obligation to observe waitlist rules. A commenter recommended that HUD expressly state whether the waitlist rules under the HOME program are violated by complying with a VAWA emergency transfer policy.
Consistent with program requirements and allowances, housing providers in covered programs are allowed to establish preferences for victims of domestic violence, dating violence, sexual assault, and stalking. These preferences, if established, must be established in accordance with statutory or regulatory requirements that govern the establishment of preferences.
HUD further clarifies in this final rule that covered housing providers must detail in their emergency transfer plans the measure of any priority that those who qualify for an emergency transfer under VAWA will receive. Existing tenants of a housing provider who request a transfer to another unit for which they would not be required to submit an application (what this rule calls an internal emergency transfer, and an example would be where no application would be required for a public housing tenant to transfer from one building within a PHA's portfolio to another building within the PHA's portfolio) should not be placed on applicant waiting lists, as these tenants are not new applicants. Where a tenant requests a transfer to a housing unit where an application would be required (what this rule calls an external emergency transfer, and an example would be a transfer to a different program or to a unit that the housing provider does not control), each covered housing provider's emergency transfer plan must provide measures to assist these tenants. For example, under the plan a provider may have established relationships with other covered housing providers in the same jurisdiction where they share updated information on available units, or relationships with victim service providers who can assist tenants in locating, and quickly moving to, a safe and available unit.
The purpose of these clarifications is to ensure individuals who qualify for an emergency transfer under VAWA receive a meaningful opportunity to transfer as expeditiously as possible and to avoid the possibility that such individuals may, for example, be placed on the bottom of an applicant waiting list with no other measures taken to assist the individuals, counter to the intent of the emergency transfer provision. The provider, through their emergency transfer plan, must develop a plan for what actions to take when a victim of domestic violence, dating violence, sexual assault, or stalking needs an emergency transfer while balancing the needs of other eligible individuals.
HUD understands that housing providers receive requests for emergency transfers other than by those who may be victims of VAWA crimes, and therefore housing providers may maintain a list of those requesting emergency transfers. Where a housing provider maintains such a list, an individual seeking an emergency transfer under VAWA must be placed on this list or on a separate list for emergency transfers under VAWA. Such lists for providing emergency transfers must be maintained consistent with program confidentiality requirements and HUD's confidentiality requirements at § 5.2007(c). Alternatively, if there is no list, an individual requesting an emergency transfer under VAWA must, at a minimum, be given any priority as an emergency transfer requestor that is consistent with the mechanism the housing provider has in place to track emergency transfer or general transfer requests.
In cases where there are multiple individuals who need and qualify for a vacant unit, HUD strongly encourages housing providers to transfer applicants who qualify for an emergency transfer under VAWA as quickly as possible, and to prioritize between multiple individuals that need transfers when there are vacant units for which the tenant requesting the emergency transfer qualifies. Housing providers may give priority to VAWA emergency transfer requests regardless of whether the housing provider prioritizes other types of emergency transfer requests. HUD encourages consideration of the danger to the victim of a VAWA crime until a transfer can be made.
Emergency transfer obligations under VAWA do not supersede any eligibility or other occupancy requirements that may apply under a covered housing program. For example, the tenancy priority for an available accessible unit required to be accessible under HUD's Section 504 regulation must still be applied to maximize the utilization of accessible units by individuals who need the accessibility features. The objective of the emergency transfer plan is to develop a plan for how to fill an available unit cognizant of the need to transfer an individual who qualifies for an emergency transfer as quickly as possible while meeting other obligations and balancing competing needs.
As for the HOME program, owners must continue to comply with existing statutory requirements when it comes to admitting tenant but are encouraged to implement preferences in their HOME-funded projects for victims of domestic violence, dating violence, sexual assault, and stalking so to assist those needing emergency transfers. HUD will issue guidance on implementing the
The rule specifies that tenants must be able to seek an internal emergency transfer and an external emergency transfer concurrently if a safe unit is not immediately available so that the tenant has a greater opportunity to move to a safe unit as quickly as possible. For example, if a tenant is not able to immediately relocate to a safe unit because there is none available for which the tenant would not have to go through an application process, emergency transfer plans must have policies that assist the tenant in making an internal emergency transfer as expeditiously as possible, for example, by placing that tenant on an emergency transfer list, and simultaneously provide the tenant with resources or assistance to seek an external emergency transfer to a unit that may be under a different provider or different program. The rule specifies that policies for assisting tenants to make external emergency transfer include arrangements with other covered housing providers to facilitate moves. These arrangements could be those that allow housing providers to share tenant files, if the tenant provides written consent to do so and any applicable confidentiality requirements are met, in order to expedite a tenant's new application process, and arrangements where covered housing providers alert one another when a unit becomes newly available for occupancy. The rule also specifies that policies may include outreach activities to organizations that assist or provide resources to victims of domestic violence, dating violence, sexual assault, or stalking. For example, as discussed earlier, covered housing providers could develop relationships with groups that assist victims covered by VAWA in making emergency transfers.
Section 5.2005(e)(3) of this final rule provides that, for purposes of notification to existing tenants, and overall public awareness, the emergency transfer plan must describe any measure of priority given to individuals who qualify for an emergency transfer under VAWA in relation to other categories of transfers and waiting lists. Under the final rule at 5.2005(e)(6) tenants who request and qualify for an internal emergency transfer must, at a minimum, be given any priority that housing providers may already provide to other types of emergency transfer requests. The rule also requires, in § 5.2005(e)(9), that emergency transfer plans must describe policies for tenants who have tenant-based rental assistance to make emergency moves with that assistance if this is something that the covered housing provider may encounter.
Additionally, HUD's regulations at 24 CFR 982.207(b)(4) and 960.206(b)(4) are revised to include victims of dating violence, sexual assault, and stalking, as well as victims of domestic violence, as those whose families should be considered for admission preferences.
With respect to the comments about project-based voucher housing, commenters are correct that, after the
With respect to prioritizing victims of domestic violence, dating violence, sexual assault, or stalking for placement in housing, HUD does not mandate that housing providers create preferences for victims of domestic violence, but encourages housing providers to provide preferences for victims of domestic violence, dating violence, sexual assault, and stalking consistent with any regulations that govern the establishment of preferences. For example, a PHA's system of local preferences must be based on local housing needs and priorities by using general accepted data sources and information obtained through the PHA Plan public comment process (24 CFR 960.206(a)(1) for public housing and 24 CFR 982.207(a)(2) for the HCV program.
Commenters also expressed concern about the victims themselves disclosing their new location to perpetrators. The commenters said that a victim, as well as other household members, should be required to self-certify a declaration that they will not disclose the location of a new unit to the perpetrator (if known) nor to anyone known to the victim, and that if they do disclose the new unit's location, the family will not be entitled to any additional unit transfers under the umbrella of VAWA protections. Commenters further suggested that any tenant who invites a perpetrator that the tenant knows is not permitted on property grounds into the tenant's unit should receive a lease violation notice.
HUD is not in a position to speculate on why a survivor might return to live in the perpetrator's unit, or how or why a perpetrator might come to know of a survivor's new address. Each victim's situation will be unique to the victim. If an individual reasonably believes that there is a threat of imminent harm, or if an individual has been sexually assaulted on the premises, and that individual requests a transfer, then that individual is eligible for a transfer under VAWA to an available unit that they believe to be safe.
Regarding transfers within the same property, HUD understands that a transfer to a unit within the same development in which the perpetrator resides might not be safe for victims. However, if the unit in the same development is the only one available, the victim should be allowed to consider transferring to the unit. This option should not be foreclosed to the victim. The victim is in the best position to make this decision. Accordingly, HUD does not prohibit emergency transfers within the same property, but encourage housing providers to endeavor to identify an available unit in another property.
Other commenters said HUD should rescind the specifications that the
Another commenter stated that if an individual is dragged off the premises and sexually assaulted elsewhere, that individual should be able to ask for an emergency transfer. A commenter said that, in the case of children at the very least, who may not disclose the assault for some period of time out of fear, it should not matter if the sexual assault occurred more than 90 days prior. A commenter said that it should not matter if a rape occurred off premises if the perpetrator of the rape is on the lease and the victim is a tenant.
Other commenters said that covered housing providers should be encouraged to apply a longer time frame when necessary, and, at a minimum, the language of HUD's proposed regulation at § 5.2005(e)(1)(b)(ii) should be changed so it is clear that nothing in the regulations prohibits housing providers from considering and approving transfers for victims of sexual assault when the assault occurred more than 90 days before the transfer request was made or the sexual assault did not occur on the premises. Commenters said the proposed regulatory provision, as written, may cause some confusion or be misinterpreted to suggest that moves to protect the health and safety of the family also must be within the 90-day time frame or experienced on the premises.
Under VAWA 2013, victims of sexual assault qualify for an emergency transfer if they either reasonably believe there is threat of imminent harm from further violence if they remain in their dwelling unit, or, the sexual assault occurred on the premises during the 90-calendar-day period preceding the date of the request for transfer. Thus, emergency transfer plans must provide that victims of sexual assault will be eligible for an emergency transfer if they expressly request the transfer and they either reasonably believe there is threat of imminent harm from further violence if they remain in their unit, regardless of where or when the sexual assault occurred, or, the sexual assault occurred on the premises during the 90-calendar-day period preceding the date of the request for transfer, regardless of whether they reasonably believe there is a threat of imminent harm from further violence if they remain in their unit. HUD has revised the Notice of Occupancy Rights under VAWA and the Model Emergency Transfer Plan to clarify that there are two ways that victims of sexual assault may qualify for an emergency transfer under VAWA. HUD also clarifies this in the rule.
With respect to a commenter's statement that a victim who was attacked by a perpetrator on the grounds of the covered housing provider but dragged from the property and sexually assaulted elsewhere should be considered as meeting the VAWA requirements for a sexual assault occurring on the premises, HUD finds that this situation would meet the requirement because, in essence, the start of the assault occurred on the premises.
Commenters asked how a transfer between properties would be coordinated and sought more guidance from HUD on transfers. Commenters asked how a PHA that administers the HCV program should effect a transfer and whether the PHA will be responsible for finding the victim a new unit. A commenter asked whether it would be acceptable for a PHA to process an expedited “move with continued assistance” (MWCA) or allow a MWCA when it would otherwise not be allowed.
Commenters asked whether it is mandatory or discretionary for PHAs to transfer a family from public housing to Section 8 housing. A commenter said that flexibility in this area would facilitate a transfer by giving PHAs the ability to transfer the household to the first unit or voucher that is available for the household's size regardless of program. A commenter also asked whether PHAs would be expected to issue a voucher to a project-based participant at risk of domestic violence.
A commenter asked what a housing provider should do if there are no units available on the current property to transfer the victim to, or there is a unit available but it does not have enough bedrooms to accommodate the victim and the victim's family.
As discussed in the proposed rule, HUD reads “under a covered housing program” to mean the covered housing provider must, at a minimum, transfer the tenant to a unit under the provider's control and assisted under the same covered program as the unit in which the tenant was residing, if a unit is available and is safe. This means housing providers may be required to transfer certain tenants to different
The proposed rule stated that, in addition, covered housing providers must allow tenants who qualify for emergency transfers to transfer to a safe and available unit that is under their control and under another covered housing program, if such transfer is permissible under applicable program regulations. This means the program regulations for both the program that the tenant is leaving and the program regulations for the program the tenant would be joining allow for a transfer between programs. After further review, HUD has removed this language from the final rule, as at the present time, there are no HUD programs to which an individual could transfer from another program without applying for housing under a new program. Tenants seeking to move to a unit covered by a different program may apply for housing under the new program. However, a housing provider is not fulfilling its emergency transfer obligation if the only relief offered to a tenant is to be placed at the bottom of a waiting list for a new program. The housing provider that administered the unit in which the tenant became a victim of domestic violence must have in its emergency transfer plan a process through which the provider will assist the victim in finding alternative housing. For example, the plan could include providing the victim with names, addresses, or phone numbers of domestic advocacy organizations that stand ready to assist victims of domestic violence on an emergency basis, and a list of other housing providers, whether private market providers or other government-assisted housing providers, that may have offered their availability to be contacted by the housing provider who has a tenant who is a victim of domestic violence, and may possibly be able to offer assistance to a victim of domestic violence.
Certain HUD programs have additional specific requirements under this rule as to actions that housing providers must take to assist tenants in transferring when a safe unit is not immediately available for victims who qualify for emergency transfers under VAWA. HOME and HTF require that the participating jurisdiction (in the case of HOME) or the grantee (in the case of HTF) must provide a list of properties in the jurisdiction that include HOME or HTF-units (depending on which program the tenant is currently under) to tenants in these programs that request and qualify for external emergency transfers under VAWA. Under this rule, the list must include for each property: The property's address, contact information, the unit sizes (number of bedrooms) for the HOME or HTF-assisted units, and, to the extent known, any tenant preferences or eligibility restrictions for the HOME or HTF-assisted units. In addition, the participating jurisdiction or the grantee may establish a preference under the program for tenants who qualify for emergency transfers, and coordinate with victim service providers and advocates to develop the emergency transfer plan, make referrals, and facilitate emergency transfers to safe and available units. For the HOME program, the participating jurisdiction may provide HOME tenant-based rental assistance to tenants who qualify for emergency transfers under 24 CFR 5.2005(e). Under the ESG and CoC programs, tenants who live in assisted units and qualify for emergency transfers under VAWA but cannot make an immediate internal emergency transfer to a safe unit receive priority over all other applicants for new assistance or housing, subject to certain eligibility restrictions. Additionally, given that 24 CFR 5.2005(e)(9) provides for tenants who are receiving tenant-based rental assistance and qualify for an emergency transfer to move quickly with that assistance, the ESG and CoC program rules require the emergency transfer plan to specify what will happen with respect to the non-transferring family member(s), if the family separates in order to effect an emergency transfer. Under HUD's Section 8 programs and Section 202 and Section 811 programs, this final rule provides that covered housing providers may adopt or modify existing admission preferences or transfer waitlist priorities to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, and must review their existing inventory of units and determine when the next vacant unit may be available, and provide a list of nearby HUD subsidized rental properties to tenants who qualify for emergency transfers under VAWA.
As noted earlier in this preamble and provided in § 5.2005(e)(12), emergency transfer obligations under VAWA do not supersede any eligibility or other occupancy requirements that may apply under a covered housing program.
Housing providers are strongly encouraged to accept emergency transfers from different housing providers, including transfers from other HUD-covered programs as long as program eligibility requirements are met, even though they are not required to do so. HUD strongly encourages housing providers who accept emergency transfer requests from other housing providers to prioritize those requests from other providers in the same manner that they prioritize VAWA emergency transfer requests that they receive from their own tenants. However, where there may be a conflict between a tenant of a housing provider needing an emergency transfer and a tenant of another housing provider needing an emergency transfer, the housing providers' first obligation is to its own tenants.
With regard to carrying out a transfer for an HCV participant, the transfer would follow current PHA policies regarding transfers. Pursuant to existing regulations, the PHA must allow the family in the tenant-based voucher program to move with continued tenant-based assistance (24 CFR 982.354(b)(4), 982.353(b)). The PHA must issue the victim a voucher allowing the victim to search for another unit in its jurisdiction, or begin the portability process if the victim wishes to move outside of the PHA's jurisdiction.
Under the PBV program, the assistance is tied to the unit as opposed, in the case of tenant-based assistance, to the family. Therefore, PBV families cannot move with their PBV assistance. However, if the victim seeks to move from the victim's unit, has been living in the PBV unit for more than one year, and has given the owner advance written notice of intent to vacate (with a copy to the PHA) in accordance with the lease, the PHA must give the victim priority to receive the next available opportunity for continued tenant-based rental assistance (24 CFR 983.261).
In response to the comment about transferring tenants between public housing and Section 8 housing, these are different programs, with separate statutory and regulatory requirements, and in order for a tenant to receive assistance through a program in which they are not currently participating, they would have to apply for housing under the new program. However, owners may, and HUD strongly encourages owners to, assist tenants in facilitating moves to other programs. Housing providers may be able to facilitate tenant transfers between different programs and different providers by
Additionally, this rule revises HUD's HOME and HTF regulations in § 92.359 and § 93.356, respectively, to require that participating jurisdictions or grantees must provide a list of properties in the jurisdiction that include HOME or HTF-assisted units, and information about each property, to tenants who qualify for, and wish to make, an external emergency transfer under VAWA. The regulations provide additional actions the participating jurisdiction or grantee may take to comply with this rule. The rule also revises HUD's ESG and CoC regulations, in §§ 576.400(e) and 576.409 (for ESG) and §§ 578.7 and 578.99 (for CoC), to provide that families living in units assisted under these programs who qualify for emergency transfers under VAWA but cannot make an immediate internal emergency transfer must be provided with priority over all other applicants for a new unit under these programs or other assistance under these programs, subject to certain restrictions.
Under HUD's Section 8 programs and Section 202 and Section 811 programs, this final rule provides, in §§ 880.613, 882.407, 882.804, 884.226, 886.139, and 891.190, that covered housing providers may adopt or modify existing admission preferences or transfer waitlist priorities to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, and must review their existing inventory of units and determine when the next vacant unit may be available, and provide a list of nearby HUD subsidized rental properties to tenants who qualify for emergency transfers under VAWA.
Commenters further stated that the permissive language in the rule, notice, and model emergency transfer plan that emergency transfers may occur if a tenant is eligible for housing in the unit to which the tenant would be transferred should be changed to mandatory language that emergency transfers shall occur if a tenant is eligible for housing. A commenter suggested that the rule should be revised to eliminate provisions that a transfer is contingent on if such transfer is permissible under applicable program regulations and that waiting lists or tenant preferences or prioritization must be considered. The commenter stated that these changes are necessary because the text, purpose, and legislative history of VAWA 2013 require that, under the statutory emergency transfer provisions, a transfer must be provided to an available and safe unit under any covered housing program. The commenter stated that the text of VAWA requires agencies to adopt a model plan that allows tenants to transfer to another available and safe unit that is assisted under “a” and not “the” covered housing program.
HUD is committed to developing ways to facilitate emergency transfers among different providers and different covered housing programs, and will continually examine ways to improve the efficacy of the current policies. For example, HUD will examine the variations in eligibility requirements and strive to identify those programs that have eligibility requirements that are comparable but not identical to see if HUD can develop a “fast-track” admission process, so to speak, for facilitating a tenant of one HUD-covered program and who is a victim of a VAWA crime to quickly meet the eligibility requirements of another HUD-covered program. Further, HUD is considering developing a model “collaborative” emergency plan in which covered housing providers in a given area work together and commit to aid one another in finding available safe units for their tenants who are victims of domestic violence.
HUD encourages housing providers to assist those who qualify for emergency transfers under VAWA to expedite applications for new housing units, in situations where a new application would be required, and to explain such measures in their emergency transfer plans. To facilitate adoption of this proposal, this rule revises the standards for PHA tenant selection criteria in public housing to state that PHAs may accept and use a prior covered housing provider's determination of eligibility and tenant screening and verification information so that victims of domestic violence, dating violence, sexual assault, or stalking who qualify for emergency transfers under VAWA can move more quickly. HUD notes that portability procedures for the Housing Choice Voucher Program in 24 CFR 982.355(c)(7) already state that when a family moves under portability to an area outside the initial PHA's jurisdiction, the initial PHA must promptly notify the receiving PHA to expect the family, and the initial PHA must give the receiving PHA the most recent form HUD 50058 (Family Report) for the family, and all related verification information.
As for the safety issue, housing providers may add in their own emergency transfer plans additional language noting the inability to guarantee the safety of a specific unit or site. It is also important to note that although housing providers may believe that they have identified a safe unit, the housing provider may not force victims of domestic violence, dating violence, sexual assault, or stalking to transfer to a site where the victim does not feel safe. Such a move would not be a transfer to a “safe” unit in accordance with VAWA 2013 and HUD's final rule.
Commenters said that it is particularly important to recognize the differing characteristics, roles and capabilities of various housing providers and property types. Commenters said that, while a PHA may be able to relocate tenants upon request, private property owners and managers are generally not in a position to transfer tenants or assist tenants in making alternative housing choices. A commenter said emergency transfer provisions should acknowledge the limitations of transfer policies and reflect the practical realities of the rental housing sector. Another commenter said that it can provide a voucher, if funding is available, to accommodate an emergency transfer request from one of its public housing units, but, due to different eligibility criteria, it cannot readily transfer public housing families to its project-based Section 8 properties.
Another commenter said that if the housing provider does not have a unit available under another covered program it administers, then the housing provider should make a referral to the appropriate agency administering HCV vouchers so that the victim may be provided with a voucher. A commenter said HUD should develop rules and procedures for the agency administering vouchers to accept referrals from covered housing providers in the agency's area to streamline the process and reduce the time in which a victim receives a tenant protection voucher. The commenter also said housing providers should make referrals to other local or regional housing providers when no appropriate units are immediately available.
A commenter asked what recourse an owner has in the event that a VAWA victim declines to move to the proposed transfer unit. Another commenter said a tenant's rejection of the proposed transfer cannot serve as a basis for good cause termination of assistance or lease termination.
With respect to the question of what recourse is available to an owner in the event that a VAWA victim declines to move to a proposed transfer unit, there is no HUD program where a tenant's rejection of a proposed transfer in accordance with § 5.2005(e) would serve as a basis for good cause termination of a lease.
As provided in § 5.2005(e)(12) of this final rule, and already stated in this preamble, emergency transfer obligations do not supersede any eligibility or other occupancy requirements that may apply under a covered housing program. Housing providers are strongly encouraged to accept emergency transfers from different housing providers, as long as all program requirements that affect the transfer, those applicable to the housing provider seeking assistance and those applicable to the housing provider willing to accept the tenant, are followed.
Commenters said that, under VAWA 2013, HUD is required to establish policies and procedures for how victims requesting an emergency transfer may receive tenant protection vouchers, subject to their availability. Commenters stated that the proposed rule did not provide policies and procedures for these vouchers, and said it makes sense to spell out a policy for these vouchers in the context of HUD's model emergency transfer plan.
Commenters emphasized that a “safe” dwelling unit could be defined as a unit in a different property, stating that a unit in the same property would not be safe, and a unit in an adjacent property may not be safe. A commenter suggested a safe unit be defined as a unit in a different property that is managed by the same owner and/or managing agent or that is within the same assisted housing program. A commenter said that in some situations, transferring to a different unit within the property may be helpful, but may not be sufficient for every situation. Another commenter said the unit should be inspected to ensure that all locks are in good working order, and the tenant should be permitted, at the tenant's expense, to add additional locks. Commenters further said the definition should include that the location of the safe unit will not be disclosed to the perpetrator by either the housing provider or anyone in the victim's household.
A commenter suggested that a “safe” unit should refer to the existing definition in 24 CFR 5.703, regarding physical condition standards for HUD housing, and if the resident declines the offer to transfer because the only available unit is next door to the tenant's current unit, then HUD must take the leading role in helping the resident find new housing. Another commenter stated that any unit receiving subsidy is subject to HUD's prevailing physical inspection standards. A commenter said a “safe” unit should be defined based on objective criteria and should not impose unrealistic requirements, and housing providers should be allowed to adopt additional transfer guidelines to enhance safety (such as neighborhood restrictions).
Other commenters said that the consideration of what is a “safe” dwelling unit should be determined by the tenant who is requesting the transfer, based on the tenant's personal knowledge and reasonable belief about what areas of the city, or what developments, would be safe for the tenant. Commenters said that establishing both physical and psychological safety can be a critical factor for survivors to recover from violence they experienced.
A commenter suggested that an “available” dwelling unit can be defined as a vacant unit of appropriate unit size, located in a different apartment complex that is covered by VAWA protections and is managed by the same owner and/or managing agent. A commenter said the word “available” refers to a subsidized unit under the same program and under the control of the provider. Another commenter said the definition of “available” should encompass any units owned or managed by the housing provider even if the unit is under a different program.
Another commenter asked if “available” has a specific time period as to when the unit will be available. Other commenters said “available” means that all options must be explored for finding a safe and available unit, in and outside of the covered housing program's control or program before denying a transfer request.
Commenters said that, overall, criteria to be considered as to what is a safe and available dwelling unit are: Expressed safety concerns; availability of safe housing, as determined by these concerns, within the housing providers' control; the availability of safe housing of the same covered housing program type; and availability of safe housing of a different covered housing program type. Other commenters said that the rule's provision that available and safe dwelling units are those controlled by the provider with the same form of
Another commenter asked that, in situations where a tenant is transferred to a different unit under a different covered housing provider, which covered housing provider will be expected to fulfill the VAWA responsibility of determining a unit as “safe.”
A commenter asked that Section 504-modified apartments otherwise reserved for households with a mobility-impaired individual, not be considered “available” to those seeking a transfer under VAWA.
Similarly, what is an “available” unit will vary in different situations. Generally, an available unit is one that is not occupied and is available to tenants given program requirements and possible considerations that may be applicable, such as eligibility requirements, unit restrictions, or term limitations. HUD will assist housing providers in identifying available units under the different HUD programs covered by VAWA.
HUD's Section 504 implementing regulations at 24 CFR part 8 describe the process by which accessible units required to be accessible under HUD's Section 504 regulation must be occupied. In order to maximize the utilization of such units by eligible individuals who require the accessibility features of the particular unit, the housing owner or manager must first offer such a unit to a current occupant of another unit of the same project or comparable projects under common control who needs the accessibility features of the vacant unit, and then to an eligible qualified individual on the waiting list needing such features. After this, the owner or manager may then offer the unit to individuals without disabilities, including individuals who need an emergency transfer under VAWA. In other words, if there remains a vacant accessible unit after engaging in this priority placement, the unit would qualify as an available unit for an emergency transfer under VAWA.
Commenters said HUD's interpretation of “under a covered housing program” is reasonable and fair if applied only to an owner of a property, and noted that a state housing agency administering project-based section 8 under 24 CFR part 883 does not “control” assisted units, nor does a HOME participating jurisdiction. Commenter said this notion of control should be explicitly stated in the regulatory text.
More generally, as explained earlier, this final rule no longer uses the term control to describe which units individuals may transfer to, and instead uses defined terms, internal emergency transfer and external emergency transfer, to describe transfer possibilities.
Other commenters said HUD can provide guidance to covered housing programs so that emergency transfer policies are institutionalized and implemented at all levels of the agency and survive employee turnover. Commenters said housing agencies should take measures to shorten transfer wait times, and to give survivors specific timeframes on when they can expect to be transferred. Commenters cited an example of a transfer policy that is working is from the Philadelphia Housing Authority. Commenters further suggested said that HUD encourage regional planning for emergency transfers and regional cooperative agreements or working groups between various housing providers of different housing programs and victim advocates.
For example, a program participant is a victim of dating violence and moves out of the assisted dwelling unit and into an emergency shelter because the victim reasonably believes to be threatened with imminent harm from further violence by remaining in the unit. The victim fails to promptly notify the PHA of the absence in violation of the PHA's policy on absence from the unit. The PHA determines that the victim has violated PHA policy on absence from a unit. The PHA undertakes proceedings to terminate assistance and terminates the Housing Assistance Payment (HAP) contract with the owner. The program participant also notifies the PHA that the program participant is a victim of dating violence and moved out of the unit because the program participant reasonably believes to be threatened with imminent harm from further violence by remaining in the dwelling unit. The PHA makes a written request to the program participant to submit documentation about the incident or incidents of dating violence. In response to the request, a Certification of Domestic Violence, Dating Violence, Sexual Assault, or Stalking is submitted to the PHA. Because the absence from the unit was a result of domestic violence, dating violence, sexual assault, or stalking and the victim reasonably believed to be threatened with imminent harm from further violence by remaining in the dwelling unit, the PHA halts proceedings to terminate assistance. The PHA would then issue a new voucher allowing the program participant to search for housing. If the program participant indicates the desire to move to an area outside of the PHA's jurisdiction, the PHA follows the provisions for portability under 24 CFR 982.355. The program participant moves to the jurisdiction of another PHA with continued assistance. This move, however, does not relieve the family of any financial obligations on the original lease.
Commenters said that when victims are fleeing or have fled abuse, they can lack access to records and it can take time to understand their legal rights when information is shared. The commenters recommended that HUD allow 28 business days from the date the written request for documentation was received to obtain third-party documentation, and allow housing providers to use their discretion to extend the deadline past 28 days.
Other commenters said that the 14-day time period should also apply to third-party documents, but the covered housing provider should be able to extend this time period, particularly if the tenant demonstrates that the tenant has begun the process of obtaining the third-party documentation. A commenter suggested that the victim be required to request any extension within the initial 14-day time period. Another commenter said the time period is appropriate with the understanding that local agencies have the discretion to set a longer locally appropriate time period and that policies governing these time periods for PHAs are subject to public review and board approval as part of agencies' planning processes.
Another commenter said HUD should clarify protocol for addressing equally compelling and competing claims, including ones with court actions pending. The commenter said that, frequently, households with competing VAWA claims also have court actions pending simultaneously and those cases may continue for years without a final resolution, and statuses that are apparently final can later change or have to be reconsidered.
Another commenter said situations in which cross-complainants submit conflicting third-party documentation, such as opposing orders of protection, create intractable situations for housing providers, which are not in a position to adjudicate family disputes or identify the primary aggressor. The commenter asked that HUD relieve PHAs of the obligation to afford VAWA protections to either complainant if documentation fails to identify a primary aggressor, or if third-party documents are themselves in conflict as to which complainant is the victim and which complainant is the perpetrator.
Commenters stated that PHAs and project owners are demanding Orders of Protection, Harassment orders, Trespass Orders, or police reports, contrary to HUD's directive to PHAs and project owners that third-party documentation cannot be required. Commenter said some PHAs and project owners require documentation that is “current,” such as a less than 30-day old police report. Additionally, commenters said some PHAs and project owners are requiring multiple forms of proof. Commenter said the regulations must be clear on this section in order to reduce these unlawful and onerous documentation practices, as they were in 2005.
Other commenters suggested adding to proposed § 5.2007 language that provides that nothing should be construed to require a participant to provide documentation other than the self-certification form, except in the case of conflicting evidence.
A commenter said relying on self-certifications to qualify applicants leaves the housing provider vulnerable to penalties that may be imposed as a result HUD program audits, and the imposition of penalties causes disruptions and delays in the program, which adversely affect the program's ability to provide services to those that need them. The commenter recommended that the rule should state that responsible entities accept self-certification as a last resort. Another commenter said self-certification, even if supported by a police report, should not be mandated as sufficient proof, and that housing providers must be permitted to require third-party verification or other documentation signed by a professional from whom the victim has sought assistance directly relating to domestic violence, dating violence, sexual assault, or stalking, or the effects of abuse. Another commenter said that the statute does not establish a hierarchy of documentation, so the rule should not limit the circumstances under which a housing provider can seek third-party documentation. A commenter said that if a program is allowed to accept self-certification then it is likely that parties will make an allegation, withdraw the allegation days later, and then make another allegation when the relationship is challenged again. The commenter said this will generate a considerable investment of time to identify alternate housing, determine eligibility, and bifurcate the lease—all to have the allegation withdrawn or proven false.
The statute also requires that HUD, or other appropriate housing agency covered under the law, approve the certification form. In order to avoid inconsistent requirements, HUD declines to allow housing providers to use their own certification forms in lieu of HUD's form. Under VAWA 2013 and this final rule, however, housing providers may allow victims of domestic violence, dating violence, sexual assault, or stalking to use a certification form that the housing provider has created, as long as it is clear that victims do not need to use that form and can use the HUD form instead (again, except for cases where there is conflicting evidence).
In contrast, another commenter said that the certification form is not designed to be comprehensible to applicants and participants, and Microsoft Office 365 Word reports a poor Flesch Readability Ease measure. The commenter also said that the form uses the term “responsible entity” without ever indicating who or what that entity is.
Another commenter said that the language used on the form to indicate the time period to submit documentation should mirror the proposed regulatory language. According to the commenter, the form says the deadline to submit documentation to a responsible entity is 14 days from the date that the entity submits a written request, rather than the proposed regulatory deadline of 14 days from the date that the tenant/applicant receives a written request. The commenter stated that the proposed certification form currently requests both the date and time of the incident(s), and said the request for the time is overly burdensome, as the victim may not recall it, or may be seeking certification based on a series of incidents. Similarly, other commenters said victims may not be able to recall dates, particularly if multiple events are involved. The commenters recommended that the form be revised to request date(s) and time and location of incident(s) “if known.” Similarly, a commenter recommended the certification line read that it is to certify that the information provided on this form is true and correct “to the best of my knowledge and recollection.”
In addition, commenters said the confidentiality clause at the end of the certification form should be amended to say that employees may not disclose, reveal, or release information, except to the extent that disclosure is consented to by the victim in a time-limited written release. The commenters said that the proposed form's inclusion of the “Public Reporting Burden” paragraph should be removed, but if this paragraph has to be on the form, it should be moved to the end of the form and the confidentiality paragraph should be moved higher on the form.
Another commenter said that the signature block should include the warning that the signatory is making such statements under penalty of perjury.
A commenter said that the certification should specially call out that the resident or participant is to take steps to ensure that the perpetrator does not learn of the new unit location, and if the victim allows the perpetrator back into the new unit then the victim may be denied a future emergency transfer if requested again.
In the interest of lessening the administrative burden on housing providers, a commenter suggested HUD allow the responsible entity to make an oral, rather than written, request for documentation. The commenter said this is especially important in emergency situations where there may not be a contact address for the victim, and when the alleged perpetrator may be put on notice of the victim's request for assistance should a written request be sent to the household.
HUD appreciates commenters pointing out that the list of available alternate documentation in the proposed certification form differed from the types of alternate documentation described in VAWA 2013 and the proposed rule. As a result, HUD has amended this language on the certification form so that it properly reflects the statutory and regulatory text. HUD has also revised the form to clarify that the deadline to submit documentation to a responsible entity is 14 business days from the date that the tenant or applicant receives a written request. Further, HUD has revised the certification form to incorporate commenters' suggestion that victims should specify the date(s) and time(s) of incidents if known. In addition, the certification signature block is revised to say that the information provided is true and correct to the best of the knowledge and recollection of the person who fills out the form. HUD has also accepted commenters' suggestion of moving the confidentiality paragraph higher on the form and moving down the paragraph in the public reporting burden, in order to emphasize the confidentiality provisions.
HUD declines to amend the certification form to say that employees may not reveal or release information, as HUD uses the term “disclose” to encompass revealing, or releasing. Because it is standard for waivers of confidentiality provisions to be time-limited, HUD accepts the proposal to add that victims must consent to disclosure in a time-limited written release. HUD also makes this change in 24 CFR 5.2007(c)(2)(i). However, HUD declines to alter the signature block to say that the signatory is making statements under penalty of perjury. The signature block states that submission of false information could jeopardize program eligibility and could be the basis for denial of admission, termination of assistance, or eviction, as terminating or denying assistance are actions within HUD's jurisdiction.
HUD also will not revise the certification form to say that the resident or participant is to take steps to ensure that the perpetrator does not learn of the new unit location. This purpose of this certification form is to document incidents of domestic violence, dating violence, sexual assault, or stalking, and is not documentation for emergency transfers. The model emergency transfer plan explains that the resident is urged to take all reasonable precautions to be safe.
HUD understands commenter's rationale for the request to allow housing providers to make oral, rather than written, requests for documentation. However, the provision requiring a written request is in VAWA 2013, and such requirement provides a record for tenants and applicants and housing providers as to compliance with the documentation provisions of this rule. HUD notes that, where possible, housing providers should give written documentation requests to victims in person.
Other commenters suggested that the notice use plain-language. A commenter explained that someone may not relate to the words “victim” or “perpetrator,” but they may relate to this language: “if someone has harmed another person in the home, there are options available.” Commenters stated that a number of sentences in the notice are lengthy, with complicated sentence structures, and they include more detail than necessary. Commenters provided examples of sentences in the notice that could be simplified, including changing: “Also attached is a HUD-approved certification form for documenting an incident of domestic violence, dating violence, sexual assault, or stalking for a tenant who seeks the protections of VAWA as provided in this notice of occupancy rights and in HUD's regulations” to “A form is attached to this notice. You can fill out this form to show that you are a victim of domestic violence, dating violence, sexual assault, or stalking, and that you wish to use your rights under VAWA.” A commenter said simpler wording would also facilitate translation into other languages.
Commenters also said the text of the notice itself, and not a footnote, should make it clear that despite the name of the law, VAWA protection is available regardless of sex, gender identity, sexual orientation, disability, or age. A commenter further stated that sections of the notice use the phrase “may not,” such as “you may not be denied admission or denied assistance,” and that changing the language to “must not” sends a stronger message about the degree to which VAWA prohibits such discrimination.
A commenter recommended that the section of the notice on removing the abuser from the household, the notice should say “HP can (rather than “may”) choose to divide your lease. . .” to more clearly convey that the housing provider has the discretion to bifurcate a lease. The commenter said that the notice does not mention that the remaining tenant can try to establish eligibility for another housing program covered by VAWA, and tenants may not be aware of this option. The commenter further said the notice should be clarified to say the housing provider
Commenters said the notice also needs to make clear that the tenant or applicant asserting VAWA protections can choose which form of acceptable documentation to provide, except in circumstances where there is conflicting evidence. The commenter further said that in discussing the types of documentation that could be provided as a record of Federal, State, tribal, territorial, or local law enforcement agency, providing one or two examples (
A commenter stated that, in the section of the notice of reasons a tenant may be evicted, it should be clear that victims can be evicted or terminated if the housing provider demonstrates that the victim's continued tenancy poses an “actual and imminent threat” to other tenants or employees, and should explain what this means. The commenter suggested this section also note that eviction or termination should be pursued only when there are no other actions that could be taken to reduce or eliminate the threat.
Commenters said the notice is addressed to “all tenants and prospective tenants,” and this appears to cover even eligible households that have not applied for assistance. Commenters said HUD should only require providers to notify existing participants and applicants. A commenter said the notice grossly oversimplifies the process required to remove a member from the household. The commenter said the provider and other household members must cooperate to remove a member who has some property rights to the housing or assistance, and it is not the provider alone who can divide the lease or remove the abuser from the household.
Other commenters said the form contains extraneous information. A commenter stated that the first bullet describing documentation includes a description of the information contained in the certification, but if participants and applicants receive the certification form, the notice need not describe its contents. The commenter further stated that after listing professionals who may provide documentation, the notice contains a parenthetical that says, “(collectively, “professional”),” and this extra language adds nothing.
A commenter said the transfer right must be described in the proposed notice in more detail for a tenant to sufficiently be able to act on that right and to understand that this is an emergency transfer and not a traditional, slow transfer process, and the notice should explain any necessary documentation requirements. A commenter said the language should not use the term “another unit” because it gives the impression that the move is only to a unit within the existing covered housing project. The commenter said the language should state that “if you reasonably believe there is a threat of imminent harm from violence if you stay in the same unit or development where you live now, or if you are a victim of sexual assault that recently happened at your development, you have the right to ask for an emergency transfer to a different unit, including a unit in a different development, different type of affordable housing, and in a different location.” The commenter said the notice should also emphasize that requests for transfers and the location of the move will be kept confidential.
Another commenter said the notice should include language that informs an applicant of the possibility of overcoming a negative rental, tenant, or criminal history if that history relates to their victimization. The commenter said this will allow a survivor to obtain and provide appropriate information to the covered housing program at the outset of the application process.
HUD has also revised the notice as suggested by commenters to improve clarity. The notice now explicitly states that dividing a lease means the same thing as bifurcating a lease, but the notice does not specify which housing provider would bifurcate a lease, as this differs across programs. Housing providers that issue the notice of rights should clarify who is responsible for lease bifurcation. The revised notice also clarifies that a housing provider can, but is not required to, ask for documentation, and may but is not required to, extend the deadline to submit documentation. The revised notice also states that except for cases where there is conflicting evidence, it is the choice of the victim of domestic violence, dating violence, sexual assault, or stalking which form of documentation to submit. The notice also now states that examples of reports from law enforcement agencies and courts include police reports, protective orders, and restraining orders, among others.
In response to the comment that the notice should explain when a tenant could be evicted or assistance could be terminated, the revised notice states that the VAWA protections may not apply if the housing provider can demonstrate that not evicting a tenant or terminating the tenant's assistance would present a real physical danger that would occur within an immediate time frame, and could result in death or serious bodily harm to other tenants or those who work on the property. The notice explains that housing providers should only evict tenants or terminate assistance when they cannot take other actions to reduce or eliminate the threat. Further, the revised notice is addressed to tenants and applicants, rather than tenants and prospective tenants. The revised notice also explains the criteria for requesting an emergency transfer, but it does not provide further information on emergency transfers, which vary across housing programs and providers, and instead notifies tenants that their housing provider has an emergency transfer plan that contains more information, and tenants have a right to see the plan.
There are some changes suggested by commenters that HUD did not make to the revised notice. HUD has not replaced the phrase “may not” throughout the notice to “must not.” HUD maintains that “may not” sufficiently denotes that an action is prohibited. HUD also declines to replace the word “may” in the sentence that
A commenter suggested that the notice encourage tenants or applicants who think they may qualify for VAWA protections to seek the assistance of a legal services attorney or victim services provider.
The revised notice now explicitly states that tenants and applicants may be entitled to additional housing protections for victims of domestic violence, dating violence, sexual assault, or stalking under other Federal laws, as well as under State and local laws.
Other commenters said that while VAWA 2013 requires HUD to develop a notice of rights, the form of the notice is not prescribed in the statute. Commenters suggested that a separate notice is not required, and the commenters referenced a 2012 Senate Committee report saying that the Committee intended that notification be incorporated into existing standard notification documents that are provided to tenants. Commenters said that such incorporation would reduce administrative burden. A commenter said owners could be required to include language about VAWA protections in any notice of rejection or termination. The commenter said that since such notices must provide residents and applicants an opportunity to appeal eviction or termination, these notices would be an appropriate place to explain that being a victim of an act covered under VAWA would be grounds for reconsideration. According to the commenter, incorporation of VAWA protections into existing notification documents would dispense with the need for a separate document on VAWA protections.
Another commenter stated that the notification process conflicts with the Paperwork Reduction Act by requiring more paper, and adding an individual document, rather than incorporating the notice into other documents, increases the chances that a tenant will not see the notification because a housing provider may forget to provide it, or because the tenant will not read it. Commenter further stated that housing providers should not be required to provide the entire VAWA policy in tenant selection plans or in House Rules.
HUD maintains the provisions in the proposed rule that require descriptions of VAWA protections in leases, lease addendum or contracts, as specified in the regulations for the HOME, HOPWA, ESG, and CoC programs. For public housing and section 8 programs covered by VAWA 2005, this rule does not eliminate any existing notification requirements. Prior to this rule becoming effective, 24 CFR 5.2005(a)(4) provided that a HUD-required lease, lease addendum, or tenancy addendum, as applicable, must include a description of specific protections afforded to the victims of domestic violence, dating violence, or stalking, as provided in this subpart. This final rule clarifies that this remains a requirement, and adds that a description of protections afforded to victims of sexual assault is also required.
Some commenters said that requiring providers to send copies of regulations is an overly burdensome requirement that would impose considerable cost on providers for printing and mailing without adding anything to most recipients' understanding of their protections under VAWA. A commenter stated that tenants and applicants could potentially receive copies of the rule multiple times (as an applicant, if denied assistance, or if notified of termination or eviction), and there is no need to receive multiple copies of the regulations. Another commenter said including attachments of the regulations and a listing of local organizations offering assistance to victims of domestic violence is unnecessary and can lead to greater confusion for victims during a stressful time.
Other commenters said that submitting these notices to all denied applicants could be administratively prohibitive. A commenter stated that for its HOME projects, it currently administers an online housing lottery that frequently results in tens of thousands of applications, many of which are pre-determined to be ineligible based on measures like income. Commenter said that such applicants do not receive rejection letters and it would be unreasonable, impracticable, administratively burdensome, and confusing to applicants, for commenter to send these families a VAWA notice. The commenter stated that it would more reasonable to provide the VAWA notice to those applicants who have been selected by the lottery and were subsequently interviewed but found to be ineligible. The commenter asked that the final rule provide such clarification for the benefit of agencies that are responsible for marketing units of covered programs.
A commenter said that covered housing providers may not know which tenants are due a notice, or the provider may not know which program applies, so the notice should not be given to existing tenants until either recertification or lease renewal. Another commenter said that to lessen the rule's administrative and financial burden, housing providers should be permitted to provide the notice at lease renewal.
Other commenters recommended that HUD give housing providers flexibility regarding how to distribute the notices to existing tenants, in accordance with existing procedures. Other commenters emphasized that notice be given to all current tenants, regardless of whether their programs were previously covered by VAWA, because under VAWA 2005 there was no uniform notice received by all tenants and VAWA 2013 includes new housing protections. Another commenter suggested that a general mailing to all of the tenants may be the only way to reach everyone in a timely manner.
Commenters also recommended that, at minimum, tenants should receive notice on an annual basis as a matter of course going forward to ensure distribution is not simply limited to times where the existing tenants are facing eviction or termination. A commenter suggested that HUD require housing providers to host routine information sessions, about tenants' and covered program participants' rights pursuant to VAWA and should require housing providers to review VAWA
Another commenter stated that short notices indicating that more information is available in housing providers' offices would aid disseminating information about VAWA protections, as would posting these notices in common area locations. Commenter also stated that it should be clear that staff of the housing provider is available to review this material with tenants and to answer questions. The commenter further suggested using all available media to alert tenants of VAWA protections, and to do so in easy to understand language.
Commenters said it would be very helpful if HUD translated the documents and posted them on HUD's Web site. Commenters said that HUD's translation of the notice and forms would be an important step towards ensuring that victims with limited English proficiency (LEP victims) would be aware of their rights under VAWA 2013. Commenters said they believe that HUD is in a much better position than individual housing providers to provide translations expediently, particularly for languages with smaller constituencies. Commenters said that, in some areas, housing providers would not otherwise be directed by the LEP Guidance to provide translated copies of the notice, but would instead be directed by the LEP Guidance to orally interpret the notice's contents. Commenters said that HUD has previously provided translations of forms, including the self-certification forms issued under VAWA 2005 (in 13 languages), and translated versions of the VAWA 2005 lease addendum, as well as non-VAWA-related documents.
The commenters said that centralizing translation responsibility at HUD imposes consistency and uniformity in translation, and allows for quality control, and would create a central place whereby advocates can express concerns about any inaccuracies with the translations. Commenters also said that it is important for HUD consider not only direct translation of notification/forms, but also transcreation
Another commenter said that it believes VAWA 2013's mandate that HUD develop a notice of housing rights includes developing translated versions of the notice. Commenter said covered housing providers should not be charged with developing any version of the notice or the VAWA self-certification form, including these forms' non-English-language counterparts.
Housing providers must also ensure that communications and materials are provided in a manner that is effective for persons with hearing, visual, and other communication-related disabilities consistent with Section 504 of the Rehabilitation Act, the Americans with Disabilities Act, and their implementing regulations. Housing providers must provide appropriate auxiliary aids and services necessary to ensure effective communication, which includes ensuring that information is provided in appropriate accessible formats as needed,
With respect to LEP obligations, providers must take reasonable steps to ensure meaningful access to their programs and activities to LEP individuals. Please see the Department's
A commenter said that all adult family members should be given notice of any proposed action by the housing provider due to a VAWA-related incident, and said a minimum of 30 days' notice should be provided. The commenter said that if the victim has fled the unit and given the housing provider a new address, then the provider should send notice to the new address.
Another commenter asked if there a timeframe by which HUD will be required to develop this notice, and whether covered housing providers will be required to use, distribute, and abide by this notice, or whether it will be optional.
A commenter said that HUD's proposed rule would have required covered housing providers to give the notice of occupancy rights and certification form to applicants and tenants along with “any notification of eviction or notification of termination of assistance,” but many different notifications are generated in the course of holdover, licensee, and termination of tenancy proceedings. The commenter asked HUD to specify which documents constitute a “notification of eviction” or “notification of termination of assistance,” and clarify that housing providers are only required to give a tenant the notice once during the course of any tenancy termination or eviction proceeding.
HUD's final rule does not require housing providers to document in tenant files that they provided the required notice at the required times, nor does HUD's final rule require an “acknowledgement of receipt.” Further, this final rule does not provide
However, as explained further below, HUD clarifies in this final rule that the 90-day time period will not apply in situations where there are statutory prohibitions to its application. The 90-day period also will not apply where the lease will expire prior to termination of the 90-day period, and, as a result of the lease expiration, assistance is terminated. However, the expiration of the lease will not necessarily terminate assistance in the HOPWA program.
HUD stresses that the reasonable time period to establish eligibility following a lease bifurcation is triggered only in situations where the tenant removed from the unit is the one family member whose characteristics qualified the rest of the family to live in the unit or receive assistance. In many covered housing programs, including HOME, HTF, ESG, RHSP, and Section 221(d)(3), the reasonable time period provisions of this rule related to lease bifurcation will never be triggered because the family's eligibility is based on the characteristics of the family as a whole, not the characteristics of any one family member. Therefore, the eligibility of remaining tenants in these covered housing programs will have already been established at the time of bifurcation. For the Section 236, public housing, and Section 8 programs, which allow pro-ration of rent or assistance for certain families where eligibility has not been established for all members, the remaining tenants following a VAWA lease bifurcation might still need to establish their eligibility for the covered housing program if they have not provided documentation of satisfactory immigration status.
For each covered housing program, HUD has reviewed the governing statutes and explains in the below chart why remaining tenants might not have established eligibility for a program, and in those circumstances, specifically what may impact the prescribed 90- day time period for those remaining family members to either establish eligibility for a covered housing program or to find new housing following a VAWA lease bifurcation.
As shown in the above chart, under the Section 202 and Section 811 programs, there are requirements that the tenant be 62 or older (section 202) or disabled (section 811). Section 202 of the Housing Act of 1959 (12 U.S.C. 1701q) (section 202) and section 811 of the National Affordable Housing Act (42 U.S.C. 8013) (section 811) require units to be leased to eligible low-income disabled persons or families. Under the Section 202 and Section 811 statutes, HUD cannot continue to subsidize a unit for remaining family members after a lease has been bifurcated if at least one of the remaining family members has not established eligibility for the program. Therefore, although this regulation provides that if a landlord chooses to bifurcate a lease under VAWA for a unit with a Project Rental Assistance Contract (PRAC) under the Section 202 or Section 811 programs, and the remaining family members have not established eligibility for the program, the landlord must provide a reasonable time period of 90 days for the remaining family members to remain in the unit, HUD will no longer be able to provide a subsidy to that unit during the time when it has not been established that an eligible individual is residing in the unit.
The above chart also provides a shorter reasonable time period in cases where the remaining tenant in a unit covered under the 202/8 program, Section 236 program, public housing, or a Section 8 assisted unit is not eligible because of immigration status. This is because Section 214 of the Housing and Community Development Act of 1980 (42 U.S.C. 1436a(d)(4)) requires that assistance under these programs be terminated after 30 days if the remaining family member has not submitted documentation evidencing a satisfactory immigration status or a pending appeal of a verification determination of the family member's immigration status.
Commenters said that there are certain parts of the eligibility process that are out of the control of the housing provider as well as the household members, such as income verifications by third parties. In instances where the survivor cannot establish eligibility, commenters recommended that an additional 60 days or more be granted. Commenters cited a critical shortage of affordable and public housing as the reason for a need for a longer time period. Another commenter said that, under the HCV program, 30 calendar days to find alternative housing is not a reasonable timeframe, taking into account voucher holders' success rate and low local vacancy rates. Commenter
A commenter said it understands the desire to establish uniform time periods to ensure that expectations are clear for both survivors and housing providers, but a system that focuses on activities and goals, rather than strict timelines, would better recognize the external and domestic violence-related barriers to housing. The commenter said that, if an explicitly-defined time limit is necessary, HUD allow housing providers to waive the requirement whenever needed.
In contrast to the above comments, other commenters said an eligibility determination can generally be completed in significantly less than 60 days, and suggested that 90 days should be established as the maximum amount of time allowed to establish eligibility. A commenter suggested that once a family is determined to be ineligible for a program, the family should be given 30 days to vacate the unit. Some commenters said the rationale for the combined 90-day time period is unclear. Another commenter asked when the victim would not be able to establish eligibility, and when a reasonable time period to find other housing would be necessary.
Other commenters suggested that it should not take long to establish eligibility for the HUD program as properties have the household's most recent certification and necessary information. A commenter said that 60 days is too long for the initial period to establish eligibility, given the current waiting lists for individuals and families already determined to be eligible and, in the interest of lessening the burden on housing providers, HUD should permit PHAs the discretion to shorten the initial period to establish eligibility up to 30 days. Other commenters said it would take more time to find new housing than it would to establish eligibility in tight housing markets, and suggested that HUD reverse the timeframes to provide remaining occupants 30 calendar days to establish eligibility and, if they cannot, 60 calendar days to find alternative housing. Commenters said that, whatever time period is granted, it should not be separated into two distinct time periods since that is confusing and the potential is high that the family will not start looking until after they are determined to not be eligible. Commenters said these time periods provided in the proposed rule appear to ignore the complexity of bifurcation of a lease under the HCV program where, in addition to establishing eligibility and locating alternative housing, a household may also need to negotiate a new lease.
A commenter requested clarification from HUD regarding the PHA's responsibilities during this initial period and whether only the tenant's eligibility needs be established, and it is not the case that the PHA must have processed the new paperwork and have either the unit ready for move-in or the assistance ready for the tenant's use within this initial period. A commenter said the burden should be on the tenant to meet their obligation to provide the required information to establish eligibility within this initial period.
Another commenter said that, in an era of greatly diminished financial resources to administer existing housing programs, housing providers should be able to choose at their discretion to provide the tenant time to establish eligibility and find new housing as the housing provider determines reasonable given housing market conditions in the area of the housing provider. In contrast to this comment, another commenter said that there should be consistency across HUD programs to provide certainty as to how much time a tenant would be given to relocate in the event of bifurcation.
HUD declines to expand or eliminate these time periods because, under VAWA 2013, lease bifurcation is not mandatory, and HUD does not want to dissuade housing providers from considering this as an option by requiring housing providers to allow those who may be ineligible for a covered housing program—because they do not meet income or age or any other program requirement—to remain in their units for lengthy time periods. Given the high demand for housing subsidized by HUD by numerous populations, including the homeless, persons with disabilities, and the elderly, as well as other victims of crimes, HUD declines to provide for further extensions. HUD also declines to abbreviate these time periods in the interest of providing greater numbers of tenants with sufficient time to establish eligibility for a covered program, or find new housing after a lease is bifurcated. For similar reasons, HUD eliminates in this final rule the provision that housing providers may extend the reasonable time period subject to authorization under the regulations of the applicable housing program.
For the HCV program, the victim and PHA do not have to wait for an owner to bifurcate the lease for the PHA to offer continued assistance for a new unit. While the family would not have to wait for bifurcation to occur, it would have to wait for eligibility to be determined.
The period to establish eligibility and find new housing is limited to those activities, and does not include any possible additional processing or inspection time.
Another commenter said it does not understand why HUD, in application of VAWA rights and protections, makes the distinction between project-based assistance and tenant-based assistance. The commenter recommended that tenants be allowed to stay in their units while attempting to establish eligibility, and that there be no time period imposed on remaining tenants trying to transfer to tenant-based assistance. The commenter said its recommendation is particularly important because the evicted perpetrator who has the tenant-based assistance is entitled to due process rights, and if the abuser or perpetrator chooses to exercise these rights, the timeline of when a victim can establish eligibility for the tenant-based assistance becomes very unpredictable.
Another commenter asked HUD to identify the HUD's programs to which it refers when referencing HUD “tenant-based rental assistance” and “project-based assistance,” and to clarify which programs are subject to the reasonable time period accommodation. The commenter stated that the proposed rule advised that agencies administering Section 8 voucher programs should provide the reasonable time period for a maximum period of 90 days, but then said that the reasonable time period does not apply, generally, if the only assistance provided is tenant-based rental assistance.
This final rule does not maintain § 578.99(j)(8) of the proposed rule, which, as noted above, says that the reasonable time periods in 24 CFR 5.2009 do not apply to the CoC program, but instead drafts a separate bifurcation section at § 578.99(j)(7). However, HUD maintains that the reasonable time requirements do not apply because they would conflict with other CoC program requirements.
With the exception of permanent supportive housing projects, the eligibility of the household is based on the entire household, not just one member, so in the event of a lease bifurcation the household would retain the housing for the length of time remaining in their original period of
HUD's proposed language in § 5.2009(a)(1), which provides that a covered housing provider may bifurcate a lease in order to evict, remove, or terminate assistance to an individual who engages in criminal activity directly relating to domestic violence, dating violence, sexual assault or stalking against an “affiliated individual or other individual,” mirrors language in VAWA 2013. HUD interprets this statutory language to mean that a housing provider may bifurcate a lease to remove a member of the household who engages in criminal activity directly relating to domestic violence, dating violence, sexual assault, or stalking, against any individual.
Generally speaking, a lawful occupant will not have rights to a unit under a covered housing program unless the lawful occupant is a tenant on the lease. Bifurcation is not the appropriate remedy to remove a household member who is not on the lease and who is not a tenant. There would be no need to divide the lease to remove a household member who is not on the lease. As explained elsewhere in this preamble, under VAWA, a covered housing provider may not evict or terminate assistance to a tenant solely on the basis that the tenant has an unauthorized abuser or perpetrator in the household, where the unreported household member is in the unit because he or she has committed an act of domestic violence against the tenant, and the tenant is afraid to report him or her.
A commenter said that, given that the termination of occupancy rights must be carried out in accordance with State and/or local laws, the rule's bifurcation provision does not provide a helpful tool for housing providers to expedite dividing the family if both the victim and perpetrator have property rights to the unit and, in such cases, the housing provider could only relocate the victim to another unit and follow a separate track to evict or terminate the perpetrator in accordance with due process procedures. Commenters asked for advice on how to address a situation where the tenant and owner disagree about bifurcation of a lease.
If a PHA terminates assistance to an individual because that individual was a perpetrator of a crime under VAWA, that does not mean that an owner must bifurcate the lease if the unit has other household members. Similarly, a PHA cannot require an owner to terminate or bifurcate a lease where the PHA has terminated assistance for reasons unrelated to VAWA. Further, § 982.53 of this rule provides that the owner, and not the PHA, is the covered housing provider that may choose to bifurcate a lease.
For housing choice and project-based vouchers, if an owner bifurcates a lease, the owner must immediately notify the PHA of the change in the lease and provide a copy of all such changes to the PHA. This requirement is in 24 CFR 982.308(g) for the tenant-based voucher program and 24 CFR 983.256(e) for the project-based voucher program. With the exception of PHA-owned units, the PHA is not a party to the lease and therefore cannot bifurcate a lease agreement between an owner and a tenant. It is up to the owner to bifurcate the family's lease and to evict or remove the perpetrator from the unit. Under VAWA 2013 and as reflected in this rule, bifurcation of a lease is an option and not a requirement, so an owner would not be required to bifurcate a lease.
HUD notes that any eviction, removal, termination of occupancy rights, or termination of assistance must be undertaken in accordance with the procedures prescribed by Federal, State, or local law for termination of leases.
Commenters said housing providers should work with victims to determine if they are eligible for a HUD program, and HUD should continue to provide housing assistance to tenants who are trying to establish eligibility for a program or find new housing. Commenters said that at the end of the eligibility period, owners or agents should prepare a recertification showing any changes in household composition or HUD assistance and, if the victim is not eligible for assistance, the termination of subsidy or tenancy should not be effective until the last day of the month following a 30-day notice period. Commenter said that not ensuring assistance for victims and their families will lead to evictions and homelessness. A commenter said housing providers should continue to pay subsidies until the reasonable time period has elapsed.
Another commenter said that tenants who remain in the units after lease bifurcation should pay the same amount of rent owed before the bifurcation, or, the minimum rents as outlined in applicable program rules, until the time periods in the regulations to establish eligibility and find other housing runs out or until the family is able to establish eligibility for a covered housing program or has found other housing. The commenter said that, for those covered housing programs that do not have minimum rents, HUD should require that the remaining tenants in these units to pay 30 percent of the remaining tenants' income while attempting to establish eligibility or while looking for new housing. The commenter also said these interim rents should include exemptions for remaining tenants who cannot pay because of the violence or abuse.
Commenters said the final rule should be clear that housing providers are not responsible for rent payments, and should not otherwise incur losses, after a lease is bifurcated. Commenters said HUD should clarify that remaining tenants are responsible for rent payments and other lease obligations during the period when individuals are trying to establish eligibility for a covered housing program or find alternative housing, or HUD should commit to continuing assistance to the unit during the reasonable time period. A commenter said HUD should continue to provide assistance for the amount shown on the tenant certification.
Another commenter said HUD should give housing providers additional financial resources commensurate with the reasonable period, and housing providers should not be forced to forgo rent, housing assistance payments, operating funds, or other funds that they would otherwise receive. A commenter said the rule should include language that housing providers are not required to provide housing and utilities free of charge during reasonable time periods.
Other commenters said an interim recertification should be completed during the reasonable time period and interim rent should be established based on the income of remaining family members. A commenter said that, if the remaining tenant is ineligible to receive a subsidy, the rent could be set at current market rate for a section 8 or PBV tenant and flat rent limits for public housing tenants. A commenter said that use of these rents would provide incentive for participants to resolve eligibility issues quickly and help protect providers from revenue losses.
A commenter said that while eligibility approval is pending after a lease bifurcation, HUD's rule should require that any increase in the remaining family's share of rent be effective the first day of the month following a 30-day notice of changes to the rent obligation. The commenter said this time frame is consistent with current rules governing interim rent increases for HUD Multifamily Housing and should be implemented in other Federal housing programs.
This rule does not adopt a policy that, after evicting an abuser, a housing provider has the right to reject any future application where that abuser is part of this household, as this may be prohibited by State, local, and Federal laws, as well as HUD program requirements, and is outside the scope of this rulemaking.
To ensure implementation, HUD is requiring that covered housing provider keep a record of all emergency transfers requested under its emergency transfer plan, and the outcomes of such requests, and retain these records for a period of three years, or for a period of time as specified in program regulations. HUD is also providing in the “Notice of Occupancy Rights” contact information for individuals to report a covered housing provider that fails to comply with this regulation.
A commenter said HUD staff and housing providers should be required to participate in annual training to ensure compliance with VAWA. Another commenter urged HUD to consider significant technical assistance to PHAs around domestic violence and the VAWA regulations—including education on financial abuse, as this may manifest itself as “nonpayment of rent” for housing providers, notification of housing rights under VAWA, and translating forms and notices into other languages.
A commenter said HUD will also need to provide program-specific guidance, as implementation of certain provisions will vary between programs. The commenter said, for example, HOME grantees and LIHTC owners may need to add language to their tenant selection plans to handle transfer requests and allow a domestic violence survivor to have access to an available unit. The commenter said HUD will also need to provide clear guidance to each field office on how VAWA 2013 should be implemented across the various HUD programs, especially in regards to unit transfers, and provide a path for escalation if there are unclear or confusing situations.
A commenter says there should not be separate duplicative requirements for LIHTCs, administered by the Department of Treasury, as HUD's HCV and PBV programs often coexist with the LIHTCs.
Another commenter said that many of the multifamily developments funded with HOME funds and expected to be funded with HTF funds are also constructed or operated with resources from other Federal agencies. Commenters urged HUD to coordinate with these agencies so that, within statutory limits, a development is not subjected to inconsistent VAWA 2013 compliance requirements.
Commenters asked that HUD clarify that communities need to include the full participation of domestic violence and sexual assault experts in their
Another commenter expressed appreciation for the inclusion of LGBT persons within the description of individuals covered by the statute in § 5.2001 and throughout the accompanying appendix. The commenter said that, in order to ensure that LGBT victims receive the full protection intended by the statute, housing providers implementing these regulations must be able to recognize LGBT victims seeking assistance, or facing termination on the basis of criminal activity linked to a domestic violence incident, as victims may be arrested alongside their abusers. The commenter said housing providers should receive adequate training to recognize such abuse and to ensure victims are eligible for an emergency transfer and are not unnecessarily denied housing.
Commenters said formalized administrative remedies are required for several reasons. Commenters said that HUD's Office of FHEO's regional offices will only investigate VAWA violations
Commenters recommended that a special assistant or advisor within the Office of the Secretary be named who would oversee coordination of VAWA implementation, including with programs not covered by HUD, and resolution of complaints of VAWA violations, and staff persons within each program covered by VAWA should be designated in HUD headquarters to respond to questions and issues with VAWA implementation and to address complaints of VAWA violations, in conjunction with regional offices. Commenters asked that the names and contact information for these staff be made public.
The commenter said that one reason why immigrant victims have had difficulties accessing transitional housing services is because several programs have imposed means testing as a way to evaluate eligibility, even though this is not required by HUD or other Federal law. The commenter said this is problematic for immigrant victims because they may be incapable of producing the required documentation, such as the ability to secure work or proof of legal employment. The commenter recommended that HUD include a provision in the implementing regulations for VAWA 2013 that prohibits all means-testing from programs that provide short term emergency shelter and transitional housing programs for up to 2 years. The commenter said access to emergency shelter and up to 2 years of transitional housing is essential for immigrant victims because it can take up to 2 years for an immigrant crime victim to prepare, file, and receive an adjudication that provides work authorization. The commenter said this inclusion would reflect VAWA 2013's new anti-discrimination protections.
The commenter asked that HUD require all HUD-funded emergency shelter and transitional housing programs to be open to all victims of domestic violence, dating violence, sexual assault, stalking, human trafficking, child abuse, elder abuse and other U visa criminal activity without regard to the victim's immigration status.
The commenter also recommended that HUD and other Federal agencies establish grant conditions for transitional housing programs that require compliance with Federal anti-discrimination laws and nondiscrimination against victims
HUD's final rule does not require PHAs to amend their documents, or require State and local governments to revise their consolidated plans, to address emergency transfer obligations. HUD notes that the HOME regulations require participating jurisdiction to have written policies and procedures that address several program requirements (for example, underwriting and subsidy layering or rehabilitation standards) while not requiring submission of those policies and procedures to HUD the participation jurisdiction will need to comply with the new requirements. HUD reviews all of its grantees to ensure compliance with its regulations, and such reviews will include compliance with these new VAWA regulations. VAWA emergency transfer policies may be reviewed during onsite monitoring of the HOME program by staff of HUD's Office of Community Planning and Development (CPD) in the Field Offices. As described earlier in this preamble, this final rule provides that emergency transfer plans must be made publicly available, whenever feasible, and always available upon request.
Commenters expressed concern that HUD is publishing new regulations in a time of historically low funding, and said that it would be difficult to comply with new requirements. Commenters said that language in the proposed rule suggests that the added cost to the housing provider is primarily paperwork, but the costs of administering the notification and documentation requirements will be significant, and there will be costs in evaluating how resident's needs must then be addressed, and then taking steps to address those needs. The commenters said providers must establish an organizational framework to ensure compliance with HUD's VAWA regulations, including the creation of a document management system, adoption of policies, and the training of staff, and the costs of these activities are in addition to emergency transfer costs. Commenters asked HUD to consider how requirements to implement VAWA could be made more efficient and effective. A commenter said HUD's estimates of burden hours should take into account the impact on the housing providers that must take various steps following receipt of these forms.
A commenter said that, according to HUD's estimates, these new regulations will impact over 208,000 covered housing providers implementing assisted rental housing programs, and will impose an additional administrative burden on those institutions of 4,392,189 hours annually, which amount to almost 2,112 full time equivalents each year. The commenters said that, since no new funding is available, as a result of VAWA's reauthorization and the new requirements imposed, housing providers' human resources will require a substantial reallocation of personnel to assure procedural compliance with VAWA and such reallocation will be at the expense of core assisted housing management tasks at a time when funding for assisted housing programs is under extreme pressure. The commenter said housing agencies already must make difficult decisions allocating human resources among competing critical tasks, and this proposed rule will add to those difficulties.
A commenter said the rule's definition of “covered housing provider” should clarify that small providers may be exempt from certain requirements due to infeasibility, or at the very least acknowledge that there are limitations based on the size of the covered provider. In contrast, another commenter was concerned about language in the proposed rule that states small entities “are not required to carry out” bifurcation and emergency transfers “that may be more burdensome, and, indeed may not be feasible given the fewer number of units generally managed by small entities” Commenters were concerned that this
With respect to the issue of translation of documents, as noted earlier in this preamble, HUD has stated that it will provide versions of the certification form and notice of housing rights in different languages.
HUD does require all recipients to provide the appropriate language assistance to the populations that they serve, and adequately serve LEP persons without delay. As the population needs and capacity of each recipient differs, the four-factor analysis is intended to be flexible to balance the need to ensure meaningful access by LEP persons, while not imposing an undue burden on recipients, which includes small businesses, small local governments and small nonprofit organizations. HUD does encourage that LEP persons utilize the language assistance services expressly offered to them by the HUD recipients, rather than family or acquaintances.
HUD disagrees that the new language limits VAWA protections. The term “premised” better conveys that there must be a connection between the alleged violation and the domestic violence to trigger the protections of VAWA. In contrast, the term “unrelated” made it more difficult for a covered housing provider to determine whether a tenant's lease violation was related to an act of violence necessitating VAWA protections. “Premised” is more exact, less discretionary, and less open to misinterpretation. The term provides covered housing providers with uniform guidance to protect victims of domestic violence, while continuing to administer their program.
Another commenter said it would be helpful for HUD to provide technical assistance on matters such as: How to maintain an auditable trail while also protecting the privacy of details of a tenant's status; whether VAWA documentation should be retained separately from the tenant file, and if so how actions such as transfers should be documented in the tenant file (for example, listed as VAWA or “emergency circumstances” more broadly); and how to maintain privacy in electronic records, including the new address for the household, and establishing safeguards for information accessible to agency staff.
Other commenters recommended clarifying, in proposed § 5.2007(c)(2), that all methods of information sharing are prohibited, and cross referencing this prohibition in the Notice of Occupancy Rights. Commenters said § 5.2007(c)(2) should be revised to say that covered housing providers shall not disclose, or “reveal or release” such (confidential) information. Commenter recommended revising § 5.2007(c)(2)(i) to say that such information could be disclosed when requested or consented to “by an individual in an informed, written, and reasonably time-limited release.”
In contrast to these commenters, a commenter said that the prohibition against entering “any” information submitted by the tenant to the covered housing provider into a shared database raises practical operating concerns. Commenters said that while maintaining confidentiality is important, covered housing providers must be able to demonstrate compliance with occupancy requirements, including documenting requests for unit transfers, for example. A commenter said many housing providers make use of software programs to manage tenant information, and, presumably, a simple notation of “VAWA” entered into a database field to denote the reason for a unit transfer request would not violate the victim's confidentiality, and such documentation should be re-considered by HUD.
HUD declines to amend the Notice of Occupancy Rights and these regulations to broadly state that all methods of information sharing are prohibited and to say that covered housing providers shall not reveal of release (in addition to disclosing) confidential information. However, as discussed above, HUD has revised 24 CFR 5.2007(c)(2)(i) to state that disclosure must be requested or consented to in writing by the individual in a time-limited release. As discussed above, HUD believes that the confidentiality provisions in VAWA 2013 and in this rule sufficiently protect information that individuals might otherwise not share with their housing providers, out of fear of disclosure. As discussed earlier in this preamble, HUD uses the term “disclose” to encompass revealing or releasing.
A commenter said that, because HOME-grantees are responsible for ensuring HOME-funded developments are complying with all program requirements, HUD must clarify how the housing provider can responsibly share information about a VAWA claim with its regulatory oversight agency without violating any confidentiality concerns. Another commenter said it is common practice for housing providers to document in their business system requests and actions taken for administrative purposes, and covered housing providers may also consult with sources of third-party documentation regarding VAWA incidents, including but not limited to police, court officials and/or medical/social service providers. The commenter said the documentation of such incidences in business systems or communications with third-party verification sources should not be considered a violation of the confidentiality provision.
A commenter said existing regulations require PHAs to provide available information to a landlord regarding the prior residence of a tenant and information regarding prior tenancy history, and this can threaten the health and safety of an individual or family that is fleeing violence or abuse. The commenters recommended changing HCV and PBV regulations on tenant screening at § 982.307(b)(4) and § 983.255(d) to say that the PHA shall maintain the confidentiality of any information provided by the applicant relating to domestic violence, dating violence, sexual assault, or stalking, and if the applicant is a victim, the PHA shall not provide any information to an owner or landlord regarding current or prior landlords, addresses, or tenancy history subject to 24 CFR 5.2007(c).
The commenter recommended that § 91.325(c)(3) of HUD's existing regulations be changed to say that the State will develop and implement procedures to ensure the confidentiality of records pertaining to any individual who is a victim of family violence, domestic violence, dating violence, sexual assault or stalking under any project assisted under the ESG program, including those who have received VAWA protections. The commenter also recommended amending § 578.103(b) to say that all records containing protected information of those who apply for Continuum of Care assistance will be kept confidential and that VAWA-related information will not be entered into shared databases, and to reference VAWA regulations in part 5 and the VAWA statute, and to reference VAWA regulations and the statute in §§ 580.31(g), 579.304, and 579.504 of HUD's regulations.
Section 91.325(c)(3), pertaining to certifications for the ESG program, and the parallel provision in § 91.225, implement a certification requirement in the McKinney-Vento Act that is separate from VAWA protections. The ESG and CoC program rules at §§ 576.409 and 578.99(j), respectively, contain provisions about the applicability of VAWA's general confidentiality requirements in § 5.2007, and provide that the recipient or subrecipient can limit receipt of documentation by an owner to protect an individual's confidentiality. HUD declines to include additional confidentiality provisions for the ESG and CoC programs, as described by the commenter.
Commenters said the documentation requirements in the CoC and RHSP rules far exceed the VAWA standard and will likely further endanger victims. Commenters said this rule should not maintain different and more demanding documentation requirements for “original incidence” and “reasonable belief of imminent threat of further domestic violence,” but rather should simply allow a victim to attest to the violence or assault. Specifically, commenters requested that §§ 578.51, 578.103, 579.216, and 579.504 be amended to reference VAWA requirements.
The commenters said that once these documents are collected it is essential that records are kept confidential, not included in shared databases, and any records to establish status as a victim should be noted in files by employees and then destroyed or returned to the victim.
As explained earlier in this preamble, the 2013 reauthorization of VAWA occurred prior to the publication of the RHSP proposed rule and HUD will include applicable VAWA provisions on the RHSP final rule.
To assist tenants, HUD adds to the “Notice of Occupancy Rights” a provision notifying tenants that if a covered housing provider fails to comply with the requirements in the notice, or the tenant needs assistance, the tenant can contact any applicable intermediary or HUD.
Another commenter recommended that there be a lease requirement that the perpetrator cannot be listed on the new lease, and if there is a restraining order placed on the perpetrator by the victim, the victim should be required to honor that restraining order. The commenter also said the lease should require that the unit must not be substandard housing.
Other commenters said they do not support including additional lease requirements, as this can discourage private landlord participation in programs and have the unintended effect of making it more difficult for all families, and not just victims, to find housing. A commenter stated that, for ESG tenant-based rental assistance, the subrecipient is currently not responsible for reviewing the lease between the program participant and the owner, and, structurally, it makes more sense to have conditions of ESG program participation in the rental assistance agreement, as HUD has outlined in proposed § 576.106(e), and not require provisions in a lease. The commenter said that, alternatively, HUD could elect to not require either the rental assistance agreement or the lease to contain VAWA 2013 requirements where there is only short-term assistance, which would be in alignment with requirements in the HOPWA program where per proposed § 574.330, VAWA does not apply to short-term housing.
HUD declines to impose additional lease requirements, including that the perpetrator cannot be listed on the new lease and victims must honor restraining orders.
Another commenter said that it administers ESG funding for shelter operations, rapid re-housing and homeless prevention. The commenter said that, in the case of the rapid re-housing, it processes payments to owners and will assume responsibility for providing the recipient with a copy of the agreements with private owners who will provide permanent housing for
This rule's requirements, including the emergency transfer requirements, apply to both short-term and medium-term ESG rental assistance. Even short-term rental assistance is assistance that would trigger the requirements of this rule.
As discussed in the
The commenter said the proposed CPD effective dates are contrary to current HUD policy, as HUD has already reached out to participants in the HUD programs to advise them that the basic protections of VAWA were currently in effect, and do not require notice and comment rulemaking for compliance. The commenter said that in December 2013, HUD advised housing providers with HOME funds to comply with the basic VAWA protections, so it is contradictory for HUD to indicate in the Proposed Rule that VAWA only applies to units funded by the HOME program prospectively.
For similar reasons, except for the core statutory protections of VAWA, compliance with the VAWA requirements are not required for HOPWA projects with funding commitments earlier than the effective date of this rule, CoC grants awarded prior to the effective date of this rule, or ESG rental assistance agreements that are not executed or renewed after the effective date of this rule.
The commenter also said HUD's proposed regulations for lease bifurcation in the HOME program must be amended to ensure that victims' protections after lease bifurcations are consistent. The commenter said HUD does not explain why the general “reasonable time” provisions in 24 CFR part 5 do not apply to the HOME program and why the different system in proposed § 92.359(d) is necessary. The commenter said that by allowing participating jurisdictions to craft their own bifurcation policies, victims in the HOME program can have different lease bifurcation rights, and this will cause great confusion among victims. The commenter said proposed § 92.359(d) does not reflect VAWA's requirement that tenants who remain after bifurcations be provided with a “reasonable time” to establish eligibility for the existing program or for other covered housing programs, and this latter requirement must be added to the HOME regulations. In addition, commenters said that while proposed § 92.359(d)(2) mentions that remaining tenants who cannot establish eligibility for HOME project-based assistance are entitled to at least 60 days to find other housing, this additional time to find other housing is not available for HOME tenant-based assistance. The commenter also suggested adding language to the HOME regulations similar to what exists for the HCV program—the housing provider must ensure that the victim retains the assistance.
The commenter said it is unclear why HUD included proposed § 92.359(d)(1)(iii), and recommended its deletion. The commenters advised that it did not understand why the VAWA protections for the remaining tenants would differ if the existing assistance were tenant-based versus project-based. In addition, the commenter cited proposed § 92.359(e) and urged that HUD, and not the participating jurisdiction, develop the VAWA lease addendum, as this may be the only opportunity for tenants to become aware of their housing responsibilities and rights under the law and is important for quality control. The commenter said the basic elements of the lease addendum can be modeled after the VAWA 2005 lease addenda for the Section 8 housing programs, and this could serve as a template for other programs newly covered by VAWA. The commenter said that issues that must be decided locally can be identified and the unique information left blank to be completed by the appropriate covered housing provider. The commenter also commended HUD for allowing victims who receive emergency transfers to terminate their leases without penalty, and recommended that this provision be expanded for the HOME program to permit a victim in VAWA-covered housing to terminate the lease upon a 30-day written notice, except this 30-day notice would not be required in emergency transfer situations.
In addition, the commenter said proposed § 92.359(e) states that the owner must notify the entity administering HOME tenant-based program prior to starting a lease bifurcation, but the commenter is concerned this will cause unnecessary delay. The commenter recommended the provision say that when HOME tenant-based rental assistance is provided, the lease term/addendum must require the owner to notify the entity administering the HOME tenant-based rental assistance when the owner bifurcates a lease and in non-lease bifurcation circumstances before the owner provides notification of eviction to the tenant.
Further, because a housing owner must notify the participating jurisdiction prior to initiating an eviction, the participating jurisdiction will be able to provide the notice in a timely manner and HUD believes it is unnecessary to require that the housing owner also provide the notice along with the eviction notice.
This final rule revises § 92.359 to reflect the fact that, for both HOME-assisted rental projects and HOME TBRA, it is unnecessary for the participating jurisdiction to establish or implement a policy that specifies the reasonable time period for a remaining tenant to establish eligibility. The entire household must be qualified to reside in a HOME-assisted unit or to receive
HUD declines to implement commenters' suggestions regarding the VAWA lease term/addendum. The requirement in § 92.359(e) that a participating jurisdiction must develop the lease term/addendum is consistent with HOME regulations, but this rule specifies what the lease term/addendum must include. Further, HUD declines to include a section in this rule permitting a victim in VAWA-covered housing to terminate the lease upon a 30-day written notice, which would not be required in emergency transfer situations. Such a provision may conflict with State and local law and HUD will not implement it at this time without seeking further comment. In addition, this final rule does not revise the provision in the proposed rule that the owner must notify the participating jurisdiction prior to starting a lease bifurcation. The participating jurisdiction is responsible for compliance with the HOME requirements and, given this oversight role, a housing provider cannot initiate such changes without prior notification to the participating jurisdiction.
The commenter said proposed § 574.604(f) provides that the HOPWA facility or housing owner is obligated to develop the lease addendum, but urged HUD to develop the required basic elements of the lease addendum for the HOPWA program. In addition, the commenter said proposed § 5.2005(c) must be cross-referenced in proposed § 574.604(f). Commenters recommended that this section permit a victim in VAWA-covered housing to terminate the lease upon a 30-day written notice, which would not be required in emergency transfer situations.
The commenters said proposed §§ 574.604(b)(1)(i)(B) and 574.604(b)(2)(i)(B) must be amended to ensure that the responsible entity provides the VAWA rights notice and the self-certification form at all three mandated junctures, and the “or” in this paragraph should be substituted with “and.”
The commenter also said current HOPWA program regulations permit the owner to terminate a “participant's assistance . . . only in the most severe cases,” and this should be expanded with a reference to the obligation to comply with VAWA, and the current limitations on eligibility should be expanded to prohibit a denial of assistance to a VAWA victim. The commenter suggested amending § 574.310 to include these references to VAWA.
The commenter said language regarding admissions/eligibility for VAWA victims should be added to either the definition of an “eligible person” at § 574.3 or a new section in § 574.310.
This final rule amends § 574.604(c) to clarify that, for competitive grants, VAWA requirements apply to awards made on or after this rule becomes effective. The proposed rule stated that VAWA requirements are incorporated in the annual notice of funding availability and made applicable through the grant agreement or Renewal Memorandum, but the VAWA requirements are incorporated into the program's regulatory framework and will apply to competitive grants awarded on or after the rule's effective date because the grant agreement will subject the award to the entirety of 24 CFR part 574 in effect at the time of the award. The requirements do not need to be in the NOFA or made applicable through the Renewal Memorandum to apply to competitive awards.
HUD appreciates the commenter's suggestion regarding basic elements of a lease addendum, and HUD is taking these suggestions under consideration. In this final rule, HUD clarifies that, consistent with other HOPWA requirements for grantees and project sponsors, the grantee or project sponsor is responsible for ensuring that the housing or facility owner or manager adds the VAWA lease term/addendum to leases for HOPWA-assisted units and eligible persons receiving HOPWA tenant-based rental assistance. Further, HUD agrees that including a cross-reference to § 5.2005(c) in § 574.604(f) adds clarity to the rule, and accepts the commenter's recommended change. However, as discussed in relation to the HOME program, HUD declines to include a section in this rule permitting a victim in VAWA-covered housing to terminate the lease upon a 30-day written notice, which would not be required in emergency transfer situations. Such a provision may conflict with state and local law and HUD will not implement it at this time without seeking further comment.
HUD appreciates commenter's suggestion of amending §§ 574.604(b)(1)(i)(B) and 574.604(b)(2)(i)(B) to ensure that the
HUD accepts commenter's suggestion to amend § 574.310 to include references to VAWA protections.
Eligibility of HOPWA program participants is governed by HOPWA's program statute. HOPWA assistance is limited to an “eligible person” which the statute defines as “a person with acquired immunodeficiency syndrome or a related disease and the family of such person.” 42 U.S.C. 12902(12). HUD is not authorized to expand program eligibility to VAWA victims, as the commenter suggests. VAWA victims are eligible for assistance under the program if they can also meet the definition of an “eligible person.” However, HUD has provided some relief to victims in cases where the abuser is the person with HIV/AIDS. Section 574.460 allows victims in those cases a grace period to continue to receive HOPWA assistance, and an opportunity to demonstrate program eligibility.
A commenter said that the language concerning lease requirements in HUD's regulations in 24 CFR part 966 applies VAWA protections if a “current or future tenant” is or becomes a victim of domestic violence, but HUD must explain its inclusion of future tenants here, as this section concerns requirements for leases with existing tenants. Commenters asked if the term “future tenants” refers to a different set of households than “applicants.” A commenter said the proposed VAWA provisions applicable to public housing tenant leases is limited to an individual who becomes a victim, but stated that VAWA requires covered housing providers to provide the VAWA notice and self-certification form to all applicants and tenants at three junctures, regardless of whether that tenant is a victim or an affiliated member of a victim.
A commenter said that under the current regulations, a PHA may exclude certain tenants from a grievance hearing because of criminal activity, but such exclusion should not apply to victims of domestic violence, dating violence, sexual assault and stalking, and § 966.51 should be amended to reflect this.
A commenter recommended that HUD add language to § 983.253 (Leasing of contract units) to clarify that owners cannot discriminate against VAWA victims and their affiliated individuals.
For the HCV program, a commenter recommended changing § 982.202(d) to include that the PHA admission policy must state the system of admission preferences that the PHA uses, including preferences for victims of domestic violence, dating violence, sexual assault, or stalking. The commenter said the current HCV lease and tenancy rules and § 982.308 must be amended to reference the VAWA protections and any notice of eviction shall include a notice of occupancy rights and self-certification form, and that the notice and form are required as attachments to the lease.
This final rule does not revise § 966.51 as a commenter suggested. If a tenant is excluded from a grievance hearing, under § 966.51, that tenant is
This rule also does not amend § 982.202(d), as § 982.207(b)(4) already states that PHAs should consider whether to adopt a local preference for admission of families that include victims of domestic violence. This final rule does, however, amend § 982.207(b)(4) (on preferences for victims of domestic violence in the housing choice voucher program), as well as § 960.206(b)(4) (on preferences for victims of domestic violence in public housing) to clarify that preferences may be established not only for victims of domestic violence, but also for victims of dating violence, sexual assault, or stalking.
It is unnecessary to amend § 982.308 as a commenter suggested because, as explained earlier in this preamble, this final rule maintains existing 24 CFR 5.2005(a)(4), which says that the HUD-required lease, lease addendum, or tenancy addendum must include a description of specific protections for victims of VAWA crimes, for programs covered by VAWA prior to the 2013 reauthorization. Further, § 982.53(e) specifies that the PHA must apply VAWA protections, which includes the provision of the notice of VAWA rights and certification form with notification of eviction.
This final rule adds § 983.253(a)(4), which says that in selecting tenants, an owner must comply with HUD's regulations in 24 CFR part 5, subpart L (Protections for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
This rule amends § 982.207(b)(4) (preferences for victims of domestic violence in the housing choice voucher program), as well as § 960.206(b)(4) (on preferences for victims of domestic violence in public housing) to clarify that preferences may be established not only for victims of domestic violence, but also for victims of dating violence, sexual assault, or stalking.
For HOME, this rule, similar to ESG and CoC program language, clarifies that if a family living in a HOME-assisted rental unit separates under the rule's bifurcation provisions, the remaining tenant(s) are eligible to remain in the HOME-assisted unit, and if a family who is receiving HOME tenant-based rental assistance separates under the rule's bifurcation provisions, the remaining tenant(s) will retain the HOME tenant-based rental assistance and the participating jurisdiction must determine whether the tenant that was removed from the unit will receive HOME tenant-based rental assistance.
The information collection requirements contained in this rule have been submitted to the Office of Management and Budget (OMB) under the Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3520) for review and approval.
OMB reviewed this rule under Executive Order 12866 (entitled, “Regulatory Planning and Review”). This rule was determined to be a “significant regulatory action,” as defined in section 3(f) of the order but not economically significant, as provided in section 3(f)(1) of the order. In accordance with the Executive order, HUD has assessed the potential costs and benefits, both quantitative and qualitative, of this regulatory action. The potential costs associated with this regulatory action are those resulting primarily from the statute's documentation requirements.
This regulatory action is required to conform the provisions of HUD's VAWA regulations to those of title VI of VAWA 2013, codified at 42 U.S.C. 14043e
The importance of having HUD's VAWA regulations updated cannot be overstated. The expansion of VAWA 2013 to other HUD rental assistance programs emphasizes the importance of protecting victims of domestic violence, dating violence, sexual assault, and stalking, in all HUD housing offering rental assistance. By having all covered housing providers be aware of the protections of VAWA and the actions that they must take to provide such protections if needed, HUD signals to all tenants in the covered housing programs that HUD is an active part of the national response to prevent domestic violence, dating violence, sexual assault, and stalking.
In addition to expanding the applicability of VAWA to HUD programs beyond HUD's Section 8 and public housing programs, VAWA 2013 expands the protections provided to victims of domestic violence, dating violence, sexual assault, and stalking, which must be incorporated in HUD's codified regulations. For example, under VAWA 2013, victims of sexual assault are specifically protected under VAWA for the first time in HUD-covered programs. Another example is the statutory replacement of the term “immediate family member” with the term “affiliated individual.” Where HUD's current VAWA regulations provided that a non-perpetrator tenant would be protected from being evicted or denied housing because of acts of domestic violence, dating violence, or stalking committed against a family member (see current 24 CFR 5.2005(c)(2)), under VAWA 2013, the same protections apply to a non-perpetrator tenant because of acts of domestic violence, dating violence, sexual assault, or stalking committed against an “affiliated individual.” The replacement of “immediate family member” with “affiliated individual” reflects differing domestic arrangements and must be incorporated in HUD's regulations.
VAWA 2013 also increases protection for victims of domestic violence, dating violence, sexual assault, and stalking by requiring HUD to develop a model emergency transfer plan to guide covered housing providers in the development and adoption of their own emergency transfer plans. VAWA also changes the procedures for the notification to tenants and applicants of their occupancy rights under VAWA. Prior to VAWA 2013, public housing agencies administering HUD's public housing and Section 8 assistance were responsible for the development and issuance of such notification to tenants. Under VAWA 2013, HUD must develop the notice. Thus, HUD's VAWA regulations must reflect that HUD will prescribe the notice of occupancy rights to be distributed by covered housing providers.
In addition, certain provisions of VAWA 2013, particularly those pertaining to emergency transfer plans and lease bifurcations, require further clarification in order to be implemented in HUD programs. For example, this regulatory action is needed to explain whether and what documentation requirements may apply in the case of emergency transfers, and what a reasonable time period for a tenant to establish eligibility for housing under a covered housing program, or to find new housing, after a lease bifurcation would be.
As noted in the Executive Summary of this preamble, this rule provides several benefits, including expanding
The costs of the regulations, as also noted earlier in this preamble, are primarily paperwork costs. These are the costs of providing notice to applicants and tenants of their occupancy rights under VAWA, the preparation of an emergency transfer plan, and documenting the incident or incidents of domestic violence, dating violence, sexual assault, and stalking. The costs, however, are minimized to some extent by the fact that VAWA 2013 requires HUD to prepare the notice of occupancy rights, the certification form, and the model emergency transfer plan. In addition, as discussed in the preamble, costs to covered housing providers will be minimized because HUD will translate the notice of occupancy rights and certification form into the most popularly spoken languages in the United States, and HUD has prepared a model transfer request form that housing providers and tenants requesting emergency transfer may use.
In addition to the costs related to these documents, which HUD submits is not significant given HUD's role in creating the documents, there may be a cost with respect to a tenant claiming the protections of VAWA and a covered housing provider responding to such incident. This cost will vary, however, depending on the incidence of claims in a given year and the nature and complexity of the situation. The costs will also depend on the supply and demand for the available and safe units in the situation of an emergency transfer request. HUD's covered housing providers did not confront such “movement” costs under VAWA 2005, so it remains to be seen, through implementation of VAWA 2013, if the transfer to a safe and available unit can be realized in most situations in which such a request is made, and the costs a housing provider may face as a result.
The reporting and recordkeeping matrix that accompanies HUD's Paperwork Reduction Act statement, provided above, provides HUD's estimate of the workload associated with the reporting and recordkeeping requirements.
The docket file is available for public inspection between the hours of 8 a.m. and 5 p.m., weekdays, in the Regulations Division, Office of General Counsel, Department of Housing and Urban Development, 451 7th Street SW., Room 10276, Washington, DC 20410-0500. Due to security measures at the HUD Headquarters building, please schedule an appointment to review the docket file by calling the Regulations Division at 202-708-3055 (this is not a toll-free number). Persons with hearing or speech impairments may access the telephone number above via TTY by calling the Federal Relay Service, toll-free, at 800-877-8339.
The Regulatory Flexibility Act (5 U.S.C. 601
This rule implements the protections of VAWA 2013 in all HUD-covered housing programs. These protections are statutory and statutorily directed to be implemented. The statute does not allow for covered housing providers who are, or may qualify as small entities to not provide such protections to its applicants or tenants or provide fewer protections than covered entities that are larger entities. However, with respect to processes that may be found to be burdensome to small covered housing providers—such as bifurcation of the lease and the emergency transfer plan—bifurcation of the lease is a statutory option not a mandate, and transferring a tenant under the emergency transfer plan is contingent upon whether a housing provider has a safe and available unit to which a victim of domestic violence, dating violence, sexual assault, or stalking can transfer may seek transfer. Therefore, small entities are not required to carry out the bifurcation option, and emergency transfers may not be feasible given the fewer number of units generally managed by smaller entities.
This rule involves a policy document that sets out nondiscrimination standards. Accordingly, under 24 CFR 50.19(c)(3) this rule is categorically excluded from environmental review under the National Environmental Policy Act of 1969 (42 U.S.C. 4321).
Executive Order 13132 (entitled “Federalism”) prohibits an agency from publishing any rule that has federalism implications if the rule either (i) imposes substantial direct compliance costs on State and local governments and is not required by statute, or (ii) preempts State law, unless the agency meets the consultation and funding requirements of section 6 of the Executive order. This rule does not have federalism implications and does not impose substantial direct compliance costs on State and local governments or preempt State law within the meaning of the Executive order. The scope of this rule is limited to HUD-covered housing programs, as such term is defined in the rule.
Title II of the Unfunded Mandates Reform Act of 1995 (UMRA) (2 U.S.C. 1531-1538) establishes requirements for Federal agencies to assess the effects of their regulatory actions on State, local, and tribal governments, and the private sector. This rule does not impose any Federal mandates on any State, local, or tribal government, or the private sector within the meaning of UMRA.
The Catalog of Federal Domestic Assistance numbers applicable to the programs that would be affected by this rule are: 14.103, 14.135, 14.157, 14.181, 14.195, 14.231, 14.267, 14.268, 14.239, 14.241, 14.850, 14.856, and 14.871.
Administrative practice and procedure, Aged, Claims, Crime, Government contracts, Grant programs—housing and community development, Individuals with disabilities, Intergovernmental relations, Loan programs—housing and community development, Low and moderate income housing, Mortgage insurance, Penalties, Pets, Public housing, Rent subsidies, Reporting and recordkeeping requirements, Social
Aged, Grant programs—housing and community development, Homeless, Individuals with disabilities, Low and moderate income housing, Reporting and recordkeeping requirements.
Administrative practice and procedure, Grant programs—housing and community development, Low and moderate income housing, Manufactured homes, Rent subsidies, Reporting and recordkeeping requirements.
Administrative practice and procedure, Grant programs—housing and community development, Low and moderate income housing, Manufactured homes, Rent subsidies, Reporting and recordkeeping requirements.
Administrative practice and procedure, Claims, Equal employment opportunity, Fair housing, Home improvement, Housing standards, Lead poisoning, Loan programs—housing and community development, Mortgage insurance, Organization and functions (Government agencies), Penalties, Reporting and recordkeeping, Social Security, Unemployment compensation, Wages.
Grant programs—housing and community development, Loan programs—housing and community development, Low and moderate income housing, Rent subsidies.
Community facilities, Grant programs—housing and community development, Grant programs—social programs, HIV/AIDS, Low and moderate income housing, Reporting and recordkeeping requirements.
Community facilities, Grant programs—housing and community development, Grant programs—social programs, Homeless, Reporting and recordkeeping requirements.
Community development, Community facilities, Grant programs—housing and community development, Grant program—social programs, Homeless, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Homeless, Lead poisoning, Manufactured homes, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Rent subsidies, Reporting and recordkeeping requirements, Rural areas.
Grant programs—housing and community development, Lead poisoning, Rent subsidies, Reporting and recordkeeping requirements.
Aged, Grant programs—housing and community development, Individuals with disabilities, Loan programs—housing and community development, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Public housing, Reporting and recordkeeping requirements.
Aged, Grant programs—housing and community development, Individuals with disabilities, Pets, Public housing.
Grant programs—housing and community development, Public housing, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Grant programs—Indians, Indians, Public housing, Rent subsidies, Reporting and recordkeeping requirements.
Grant programs—housing and community development, Low and moderate income housing, Rent subsidies, Reporting and recordkeeping requirements.
Accordingly, for the reasons stated in the preamble, and in accordance with HUD's authority in 42 U.S.C. 3535(d), HUD amends 24 CFR parts 5, 92, 93, 200, 247, 574, 576, 578, 880, 882, 883, 884, 886, 891, 905, 960, 966, 982, and 983, as follows:
42 U.S.C. 1437a, 1437c, 1437d, 1437f, 1437n, 3535(d), Sec. 327, Pub. L. 109-115, 119 Stat. 2936, and 42 U.S.C. 14043e
(a) This subpart addresses the protections for victims of domestic violence, dating violence, sexual assault, or stalking who are applying for, or are the beneficiaries of, assistance under a HUD program covered by the Violence Against Women Act (VAWA), as amended (42 U.S.C. 13925 and 42 U.S.C. 14043e
(b)(1) The applicable assistance provided under a covered housing program generally consists of two types of assistance (one or both may be provided): Tenant-based rental assistance, which is rental assistance that is provided to the tenant; and project-based assistance, which is assistance that attaches to the unit in which the tenant resides. For project-based assistance, the assistance may consist of such assistance as operating assistance, development assistance, and mortgage interest rate subsidy.
(2) The regulations in this subpart are supplemented by the specific regulations for the HUD-covered housing programs listed in § 5.2003. The program-specific regulations address how certain VAWA requirements are to be implemented and whether they can be implemented (for example, reasonable time to establish eligibility for assistance as provided in § 5.2009(b)) for the applicable covered housing program, given the statutory and regulatory framework for the program. When there is conflict between the regulations of this subpart and the program-specific regulations, the program-specific regulations govern. Where assistance is provided under more than one covered housing program and there is a conflict between VAWA protections or remedies under those programs, the individual seeking the VAWA protections or remedies may choose to use the protections or remedies under any or all of those programs, as long as the protections or remedies would be feasible and permissible under each of the program statutes.
The definitions of
(1) A spouse, parent, brother, sister, or child of that individual, or a person to whom that individual stands in the place of a parent or guardian (for example, the affiliated individual is a person in the care, custody, or control of that individual); or
(2) Any individual, tenant, or lawful occupant living in the household of that individual.
(1) Section 202 Supportive Housing for the Elderly (12 U.S.C. 1701q), with implementing regulations at 24 CFR part 891.
(2) Section 811 Supportive Housing for Persons with Disabilities (42 U.S.C. 8013), with implementing regulations at 24 CFR part 891.
(3) Housing Opportunities for Persons With AIDS (HOPWA) program (42 U.S.C. 12901
(4) HOME Investment Partnerships (HOME) program (42 U.S.C. 12741
(5) Homeless programs under title IV of the McKinney-Vento Homeless Assistance Act (42 U.S.C. 11360
(6) Multifamily rental housing under section 221(d)(3) of the National Housing Act (12 U.S.C. 17151(d)) with a below-market interest rate (BMIR) pursuant to section 221(d)(5), with implementing regulations at 24 CFR part 221.
(7) Multifamily rental housing under section 236 of the National Housing Act (12 U.S.C. 1715z-1), with implementing regulations at 24 CFR part 236.
(8) HUD programs assisted under the United States Housing Act of 1937 (42 U.S.C. 1437
(9) The Housing Trust Fund (12 U.S.C. 4568) (with implementing regulations at 24 CFR part 93).
(1) Who is or has been in a social relationship of a romantic or intimate nature with the victim; and
(2) Where the existence of such a relationship shall be determined based on a consideration of the following factors:
(i) The length of the relationship;
(ii) The type of relationship; and
(iii) The frequency of interaction between the persons involved in the relationship.
(1) Fear for the person's individual safety or the safety of others; or
(2) Suffer substantial emotional distress.
(a)
(i) A “Notice of Occupancy Rights under the Violence Against Women Act,” as prescribed and in accordance with directions provided by HUD, that explains the VAWA protections under this subpart, including the right to confidentiality, and any limitations on those protections; and
(ii) A certification form, in a form approved by HUD, to be completed by the victim to document an incident of domestic violence, dating violence, sexual assault or stalking, and that:
(A) States that the applicant or tenant is a victim of domestic violence, dating violence, sexual assault, or stalking;
(B) States that the incident of domestic violence, dating violence, sexual assault, or stalking that is the ground for protection under this subpart meets the applicable definition for such incident under § 5.2003; and
(C) Includes the name of the individual who committed the domestic violence, dating violence, sexual assault, or stalking, if the name is known and safe to provide.
(2) The notice required by paragraph (a)(1)(i) of this section and certification form required by paragraph (a)(1)(ii) of this section must be provided to an applicant or tenant no later than at each of the following times:
(i) At the time the applicant is denied assistance or admission under a covered housing program;
(ii) At the time the individual is provided assistance or admission under the covered housing program;
(iii) With any notification of eviction or notification of termination of assistance; and
(iv) During the 12-month period following
(3) The notice required by paragraph (a)(1)(i) of this section and the certification form required by paragraph (a)(1)(ii) of this section must be made available in multiple languages, consistent with guidance issued by HUD in accordance with Executive Order 13166 (Improving Access to Services for Persons with Limited English Proficiency, signed August 11, 2000, and published in the
(4) For the Housing Choice Voucher program under 24 CFR part 982, the project-based voucher program under 24 CFR part 983, the public housing admission and occupancy requirements under 24 CFR part 960, and renewed funding or leases of the Section 8 project-based program under 24 CFR parts 880, 882, 883, 884, 886, as well as project-based section 8 provided in connection with housing under part 891, the HUD-required lease, lease addendum, or tenancy addendum, as applicable, must include a description of specific protections afforded to the victims of domestic violence, dating violence, sexual assault, or stalking, as provided in this subpart.
(b)
(2)
(i) The criminal activity is engaged in by a member of the household of the tenant or any guest or other person under the control of the tenant, and
(ii) The tenant or an affiliated individual of the tenant is the victim or threatened victim of such domestic violence, dating violence, sexual assault or stalking.
(c)
(1) A serious or repeated violation of a lease executed under a covered housing program by the victim or threatened victim of such incident; or
(2) Good cause for terminating the assistance, tenancy, or occupancy rights under a covered housing program of the victim or threatened victim of such incident.
(d)
(i) The rights of access or control of property, including civil protection orders issued to protect a victim of domestic violence, dating violence, sexual assault, or stalking; or
(ii) The distribution or possession of property among members of a household.
(2) Nothing in this section limits any available authority of a covered housing provider to evict or terminate assistance to a tenant for any violation not premised on an act of domestic violence, dating violence, sexual assault, or stalking that is in question against the tenant or an affiliated individual of the tenant. However, the covered housing provider must not subject the tenant, who is or has been a victim of domestic violence, dating violence, sexual assault, or stalking, or is affiliated with an individual who is or has been a victim of domestic violence, dating violence, sexual assault or stalking, to a more demanding standard than other tenants in determining whether to evict or terminate assistance.
(3) Nothing in this section limits the authority of a covered housing provider to terminate assistance to or evict a tenant under a covered housing program if the covered housing provider can demonstrate an actual and imminent threat to other tenants or those employed at or providing service to property of the covered housing provider would be present if that tenant or lawful occupant is not evicted or terminated from assistance. In this context, words, gestures, actions, or other indicators will be considered an “actual and imminent threat” if they meet the standards provided in the definition of “actual and imminent threat” in § 5.2003.
(4) Any eviction or termination of assistance, as provided in paragraph (d)(3) of this section should be utilized
(e)
(1) For purposes of this section, the following definitions apply:
(i)
(ii)
(iii)
(2) The emergency transfer plan must provide that a tenant receiving rental assistance through, or residing in a unit subsidized under, a covered housing program who is a victim of domestic violence, dating violence, sexual assault, or stalking qualifies for an emergency transfer if:
(i) The tenant expressly requests the transfer; and
(ii)(A) The tenant reasonably believes there is a threat of imminent harm from further violence if the tenant remains within the same dwelling unit that the tenant is currently occupying; or
(B) In the case of a tenant who is a victim of sexual assault, either the tenant reasonably believes there is a threat of imminent harm from further violence if the tenant remains within the same dwelling unit that the tenant is currently occupying, or the sexual assault occurred on the premises during the 90-calendar-day period preceding the date of the request for transfer.
(3) The emergency transfer plan must detail the measure of any priority given to tenants who qualify for an emergency transfer under VAWA in relation to other categories of tenants seeking transfers and individuals seeking placement on waiting lists.
(4) The emergency transfer plan must incorporate strict confidentiality measures to ensure that the covered housing provider does not disclose the location of the dwelling unit of the tenant to a person who committed or threatened to commit an act of domestic violence, dating violence, sexual assault, or stalking against the tenant.
(5) The emergency transfer plan must allow a tenant to make an internal emergency transfer under VAWA when a safe unit is immediately available.
(6) The emergency transfer plan must describe policies for assisting a tenant in making an internal emergency transfer under VAWA when a safe unit is not immediately available, and these policies must ensure that requests for internal emergency transfers under VAWA receive, at a minimum, any applicable additional priority that housing providers may already provide to other types of emergency transfer requests.
(7) The emergency transfer plan must describe reasonable efforts the covered housing provider will take to assist a tenant who wishes to make an external emergency transfer when a safe unit is not immediately available. The plan must include policies for assisting a tenant who is seeking an external emergency transfer under VAWA out of the covered housing provider's program or project, and a tenant who is seeking an external emergency transfer under VAWA into the covered housing provider's program or project. These policies may include:
(i) Arrangements, including memoranda of understanding, with other covered housing providers to facilitate moves; and
(ii) Outreach activities to organizations that assist or provide resources to victims of domestic violence, dating violence, sexual assault, or stalking.
(8) Nothing may preclude a tenant from seeking an internal emergency transfer and an external emergency transfer concurrently if a safe unit is not immediately available.
(9) Where applicable, the emergency transfer plan must describe policies for a tenant who has tenant-based rental assistance and who meets the requirements of paragraph (e)(2) of this section to move quickly with that assistance.
(10) The emergency transfer plan may require documentation from a tenant seeking an emergency transfer, provided that:
(i) The tenant's submission of a written request to the covered housing provider, where the tenant certifies that they meet the criteria in paragraph (e)(2)(ii) of this section, shall be sufficient documentation of the requirements in paragraph (e)(2) of this section;
(ii) The covered housing provider may, at its discretion, ask an individual seeking an emergency transfer to document the occurrence of domestic violence, dating violence, sexual assault, or stalking, in accordance with § 5.2007, for which the individual is seeking the emergency transfer, if the individual has not already provided documentation of that occurrence; and
(iii) No other documentation is required to qualify the tenant for an emergency transfer.
(11) The covered housing provider must make its emergency transfer plan available upon request and, when feasible, must make its plan publicly available.
(12) The covered housing provider must keep a record of all emergency transfers requested under its emergency transfer plan, and the outcomes of such requests, and retain these records for a period of three years, or for a period of time as specified in program regulations. Requests and outcomes of such requests must be reported to HUD annually.
(13) Nothing in this paragraph (e) may be construed to supersede any eligibility or other occupancy requirements that may apply under a covered housing program.
(a)
(2)(i) If an applicant or tenant does not provide the documentation requested under paragraph (a)(1) of this section within 14 business days after the date that the tenant receives a request in writing for such documentation from
(A) Deny admission by the applicant or tenant to the covered housing program;
(B) Deny assistance under the covered housing program to the applicant or tenant;
(C) Terminate the participation of the tenant in the covered housing program; or
(D) Evict the tenant, or a lawful occupant that commits a violation of a lease.
(ii) A covered housing provider may, at its discretion, extend the 14-business-day deadline under paragraph (a)(2)(i) of this section.
(b)
(i) The certification form described in § 5.2005(a)(1)(ii); or
(ii) A document:
(A) Signed by an employee, agent, or volunteer of a victim service provider, an attorney, or medical professional, or a mental health professional (collectively, “professional”) from whom the victim has sought assistance relating to domestic violence, dating violence, sexual assault, or stalking, or the effects of abuse;
(B) Signed by the applicant or tenant; and
(C) That specifies, under penalty of perjury, that the professional believes in the occurrence of the incident of domestic violence, dating violence, sexual assault, or stalking that is the ground for protection and remedies under this subpart, and that the incident meets the applicable definition of domestic violence, dating violence, sexual assault, or stalking under § 5.2003; or
(iii) A record of a Federal, State, tribal, territorial or local law enforcement agency, court, or administrative agency; or
(iv) At the discretion of a covered housing provider, a statement or other evidence provided by the applicant or tenant.
(2) If a covered housing provider receives documentation under paragraph (b)(1) of this section that contains conflicting information (including certification forms from two or more members of a household each claiming to be a victim and naming one or more of the other petitioning household members as the perpetrator), the covered housing provider may require an applicant or tenant to submit third-party documentation, as described in paragraphs (b)(1)(ii), (b)(1)(iii), or (b)(1)(iv) of this section, within 30 calendar days of the date of the request for the third-party documentation.
(3) Nothing in this paragraph (b) shall be construed to require a covered housing provider to request that an individual submit documentation of the status of the individual as a victim of domestic violence, dating violence, sexual assault, or stalking.
(c)
(1) The covered housing provider shall not allow any individual administering assistance on behalf of the covered housing provider or any persons within their employ (
(2) The covered housing provider shall not enter confidential information described in paragraph (c) of this section into any shared database or disclose such information to any other entity or individual, except to the extent that the disclosure is:
(i) Requested or consented to in writing by the individual in a time-limited release
(ii) Required for use in an eviction proceeding or hearing regarding termination of assistance from the covered program; or
(iii) Otherwise required by applicable law.
(d) A covered housing provider's compliance with the protections of §§ 5.2005 and 5.2009, based on documentation received under this section shall not be sufficient to constitute evidence of an unreasonable act or omission by the covered housing provider. However, nothing in this paragraph (d) of this section shall be construed to limit the liability of a covered housing provider for failure to comply with §§ 5.2005 and 5.2009.
(a)
(i) Without regard to whether the household member is a signatory to the lease; and
(ii) Without evicting, removing, terminating assistance to, or otherwise penalizing a victim of such criminal activity who is also a tenant or lawful occupant.
(2) A lease bifurcation, as provided in paragraph (a)(1) of this section, shall be carried out in accordance with any requirements or procedures as may be prescribed by Federal, State, or local law for termination of assistance or leases and in accordance with any requirements under the relevant covered housing program.
(b)
(2)
(A) Establish eligibility for the same covered housing program under which the evicted or terminated tenant was the recipient of assistance at the time of bifurcation of the lease; or
(B) Establish eligibility under another covered housing program; or
(C) Find alternative housing.
(ii) The 90-calendar-day period provided by paragraph (b)(2) of this section will not be available to a remaining household member if the statutory requirements for the covered housing program prohibit it. The 90-day calendar period also will not apply beyond the expiration of a lease, unless this is permitted by program regulations. The 90-calendar-day period is the total period provided to a remaining tenant to establish eligibility under the three options provided in paragraphs (b)(2)(i)(A), (B), and (C) of this section.
(iii) The covered housing provider may extend the 90-calendar-day period in paragraph (b)(2) of this section up to an additional 60 calendar days, unless prohibited from doing so by statutory requirements of the covered program or unless the time period would extend beyond expiration of the lease.
(c)
(a) Nothing in this subpart shall be construed to supersede any provision of any Federal, State, or local law that provides greater protection than this section for victims of domestic violence, dating violence, sexual assault, or stalking.
(b) All applicable fair housing and civil rights statutes and requirements apply in the implementation of VAWA requirements. See § 5.105(a).
42 U.S.C. 3535(d), 3601-3619, 5301-5315, 11331-11388, 12701-12711, 12741-12756, and 12901-12912.
(e)
(f)
(g)
(h)
42 U.S.C. 3535(d) and 12701-12839.
(a)
(d) * * *
(7) Comply with the VAWA requirements prescribed in § 92.359.
(a)
(2) For the HOME program, the “covered housing provider,” as this term is used in HUD's regulations in 24 CFR part 5, subpart L, refers to:
(i) The housing owner for the purposes of 24 CFR 5.2005(d)(1), (d)(3), and (d)(4) and § 5.2009(a); and
(ii) The participating jurisdiction and the owner for purposes of 24 CFR 5.2005(d)(2), 5.2005(e), and 5.2007, except as otherwise provided in paragraph (g) of this section.
(b)
(c)
(1)
(2)
(d)
(1) If a family living in a HOME-assisted rental unit separates under 24 CFR 5.2009(a), the remaining tenant(s) may remain in the HOME-assisted unit.
(2) If a family who is receiving HOME tenant-based rental assistance separates under 24 CFR 5.2009(a), the remaining tenant(s) will retain the HOME tenant-based rental assistance. The participating jurisdiction must determine whether the tenant that was removed from the unit will receive HOME tenant-based rental assistance.
(e)
(f)
(g)
(2) For the purposes of § 5.2005(e)(7), the required policies must specify that for tenants who qualify for an emergency transfer and who wish to make an external emergency transfer when a safe unit is not immediately available, the participating jurisdiction must provide a list of properties in the jurisdiction that include HOME-assisted units. The list must include the following information for each property: The property's address, contact information, the unit sizes (number of bedrooms) for the HOME-assisted units, and, to the extent known, any tenant preferences or eligibility restrictions for the HOME-assisted units. In addition, the participating jurisdiction may:
(i) Establish a preference under the participating jurisdiction's HOME program for tenants who qualify for emergency transfers under 24 CFR 5.2005(e);
(ii) Provide HOME tenant-based rental assistance to tenants who qualify for emergency transfers under 24 CFR 5.2005(e); or
(iii) Coordinate with victim service providers and advocates to develop the emergency transfer plan, make referrals, and facilitate emergency transfers to safe and available units.
(c) * * *
(1) * * *
(vi) * * * If HOME funds are provided for development of rental housing or provision of tenant-based rental assistance, the agreement must set forth all obligations the State imposes on the State recipient in order to meet the VAWA requirements under § 92.359, including notice obligations and any obligations with respect to the emergency transfer plan (including whether the State recipient must develop its own plan or follow the State's plan).
(2) * * *
(iv) * * * If HOME funds are being provided to develop rental housing or provide tenant-based rental assistance, the agreement must set forth all obligations the participating jurisdiction imposes on the subrecipient in order to meet the VAWA requirements under § 92.359, including notice obligations and obligations under the emergency transfer plan.
(3) * * *
(v) * * *
(F) If HOME funds are being provided to develop rental housing, the agreement must set forth all obligations the participating jurisdiction imposes on the owner in order to meet the VAWA requirements under § 92.359, including the owner's notice obligations and owner obligations under the emergency transfer plan.
(4) * * *
(ii) * * * If applicable to the work under the contract, the agreement must set forth all obligations the participating jurisdiction imposes on the contractor in order to meet the VAWA requirements under § 92.359, including any notice obligations and any obligations under the emergency transfer plan.
(a) * * *
(7) * * *
(x) Records of emergency transfers requested under 24 CFR 5.2005(e) and 92.359 pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of those requests.
42 U.S.C. 3535(d) and 12 U.S.C. 4568.
(a)
(d) * * *
(7) Comply with the VAWA requirements prescribed in § 93.356.
(a)
(2) For the HTF program, the “covered housing provider,” as this term is used in HUD's regulations in 24 CFR part 5, subpart L, refers to:
(i) The owner of HTF-assisted rental housing for the purposes of 24 CFR 5.2005(d)(1), (2), (3), and (4) and 5.2009(a); and
(ii) The owner and the grantee for purposes of 24 CFR 5.2005(e) and 5.2007, except as otherwise provided in paragraph (f) of this section.
(b)
(c)
(d)
(e)
(f)
(1) Establish a preference under the grantee's HTF program for tenants who qualify for emergency transfers under 24 CFR 5.2005(e); and
(2) Coordinate with victim service providers and advocates to develop the emergency transfer plan, make referrals, and facilitate emergency transfers to safe and available units.
(c) * * *
(1) * * *
(vi)
(2) * * *
(vi)
(a) General. * * *
(5) * * *
(ix) Documentation on emergency transfers requested under 24 CFR 5.2005(e) and § 93.356 pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of such requests.
12 U.S.C. 1702-1715z-21 and 42 U.S.C. 3535(d).
(a) The requirements for protection for victims of domestic violence, dating violence, sexual assault, or stalking in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply to programs administered under section 236 and under sections 221(d)(3) and (d)(5) of the National Housing Act, as follows:
(1) Multifamily rental housing under section 221(d)(3) of the National Housing Act (12 U.S.C. 17151(d)) with a below-market interest rate (BMIR) pursuant to section 221(d)(5), with implementing regulations at 24 CFR part 221. The Section 221(d)(3) BMIR program insured and subsidized mortgage loans to facilitate new construction or substantial rehabilitation of multifamily rental cooperative housing for low- and moderate-income families. The program is no longer active, but Section 221(d)(3) BMIR properties that remain in existence are covered by VAWA. Coverage of section 221(d)(3) and (d)(5) BMIR housing does not include section 221(d)(3) and (d)(5) BMIR projects that refinance under section 223(a)(7) or 223(f) of the National Housing Act where the interest rate is no longer determined under section 221(d)(5).
(2) Multifamily rental housing under section 236 of the National Housing Act (12 U.S.C. 1715z-1), with implementing regulations at 24 CFR part 236. Coverage of the section 236 program includes not only those projects with FHA-insured project mortgages under section 236(j), but also non-FHA-insured projects that receive interest reduction payments (“IRP”) under section 236(b) and formerly insured section 236 projects that continue to receive interest reduction payments through a “decoupled” IRP contract under section 236(e)(2). Coverage also includes projects that receive rental assistance payments authorized under section 236(f)(2).
(b) For the programs administered under paragraph (a) of this section, “covered housing provider” as such term is used in 24 CFR part 5, subpart L, refers to the mortgagor, or owner, as applicable.
12 U.S.C. 1701q, 1701s, 1715b, 1715
(b) Landlords of subsidized projects that have been assisted under a covered housing program listed in 24 CFR 5.2003 must comply with 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking), as described in § 200.38.
42 U.S.C. 3535(d) and 12901-12912.
(e) * * *
(2) * * * (i)
When a covered housing provider exercises the option to bifurcate a lease, as provided in 24 CFR 5.2009(a), in order to evict, remove, terminate occupancy rights, or terminate assistance to a person with AIDS or related diseases that receives rental assistance or resides in rental housing assisted under the HOPWA program for engaging in criminal activity directly relating to domestic violence, dating violence, sexual assault or stalking, the covered housing provider shall provide the remaining persons residing in the unit a reasonable grace period to establish eligibility to receive HOPWA assistance or find alternative housing. The grantee or project sponsor shall set the reasonable grace period, which shall be no less than 90 calendar days, and not more than one year, from the date of the bifurcation of the lease. Housing assistance and supportive services under the HOPWA program shall continue for the remaining persons residing in the unit during the grace period. The grantee or project sponsor shall notify the remaining persons residing in the unit of the duration of the reasonable grace period and may assist them with information on other available housing programs and with moving expenses.
(b)
(c) Data on emergency transfers requested under 24 CFR 5.2005(e), pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of such requests.
(a)
(2) Limited applicability of VAWA requirements. The VAWA requirements set forth in 24 CFR part 5, subpart L do not apply to short-term supported housing, as provided in § 574.330, except that no individual may be denied admission to or removed from the short-term supported housing on the basis or as a direct result of the fact that the individual is or has been a victim of domestic violence, dating violence, sexual assault, or stalking, if the individual otherwise qualifies for admission or occupancy.
(3) The terms “affiliated individual,” “dating violence,” “domestic violence,” “sexual assault,” and “stalking” are defined in 24 CFR 5.2003.
(b)
(1)(i) For housing assisted with HOPWA grant funds for acquisition, rehabilitation, conversion, lease, and repair of facilities to provide housing; new construction; operating costs; community residences; and project-based rental assistance, the HOPWA grantee is responsible for ensuring that each project sponsor undertakes the following actions (or, if administering the HOPWA assistance directly, the grantee shall undertake the following actions):
(A) Sets a policy for determining the “reasonable grace period” for remaining persons residing in the unit to establish eligibility for HOPWA assistance or find alternative housing, which period shall be no less than 90 calendar days nor more than one year from the date of bifurcation of a lease, consistent with 24 CFR 574.460;
(B) Provides notice of occupancy rights and the certification form at the times listed in paragraph (d) of this section;
(C) Adopts and administers an emergency transfer plan, as developed by the grantee in accordance with 24 CFR 5.2005(e) of this section, and facilitates emergency transfers; and
(D) Maintains the confidentiality of documentation submitted by tenants requesting emergency transfers and of each tenant's housing location consistent with § 574.440 and 24 CFR 5.2007(c).
(ii)(A) If a tenant seeks VAWA protections, set forth in 24 CFR part 5, subpart L, the tenant must submit such request through the project sponsor (or the grantee if the grantee is directly administering HOPWA assistance). Grantees and project sponsors will work with the housing or facility owner or manager to facilitate protections on the tenant's behalf. Project sponsors must follow the documentation specifications in 24 CFR 5.2007, including the confidentiality requirements in 24 CFR 5.2007(c).
(B) The grantee or project sponsor is responsible for ensuring that the housing or facility owner or manager develops and uses a HOPWA lease addendum with VAWA protections and is made aware of the option to bifurcate a lease in accordance with § 574.460 and 24 CFR 5.2009.
(2)(i) For tenant-based rental assistance, the HOPWA grantee is responsible for ensuring that each project sponsor providing tenant-based rental assistance undertakes the following actions (or, if administering the HOPWA assistance directly, the grantee shall undertake the following actions):
(A) Sets policy for determining the “reasonable grace period” for remaining persons residing in the unit to establish eligibility for HOPWA assistance or find alternative housing, which period shall be no less than 90 calendar days and no more than one year from the date of bifurcation of a lease, consistent with 24 CFR 574.460;
(B) Provides notice of occupancy rights and the certification form at the times listed in paragraph (d) of this section;
(C) Adopts and administers an emergency transfer plan, as developed by the grantee in accordance with 24 CFR 5.2005(e) of this section, and facilitates emergency transfers; and
(D) Maintains the confidentiality of documentation submitted by tenants requesting emergency transfers and of each tenant's housing location consistent with § 574.440 and 24 CFR 5.2007(c).
(ii)(A) If a tenant seeks VAWA protections set forth in 24 CFR part 5, subpart L, the tenant must submit such request through the project sponsor (or the grantee if the grantee is directly administering HOPWA assistance). The project sponsor will work with the housing owner or manager to facilitate protections on the tenant's behalf. Project sponsors must follow the documentation specifications in 24 CFR 5.2007, including the confidentiality requirements in 24 CFR 5.2007(c). The project sponsor (or the grantee if the grantee is directly administering HOPWA assistance) is also responsible for determining on a case-by-case basis whether to provide new tenant-based rental assistance to a remaining tenant if lease bifurcation or an emergency transfer results in division of the household.
(B) The grantee or project sponsor is responsible for ensuring that the housing owner or manager develops and uses a HOPWA lease addendum with VAWA protections and is made aware of the option to bifurcate a lease in accordance with § 574.460 and 24 CFR 5.2009.
(c)
(d)
(i) At the time the person is denied rental assistance or admission to a HOPWA-assisted unit;
(ii) At the time the person is admitted to a HOPWA-assisted unit or is provided rental assistance;
(iii) With any notification of eviction from the HOPWA-assisted unit or notification of termination of rental assistance; and
(iv) During the 12-month period following December 16, 2016, either during annual recertification or lease renewal, whichever is applicable, or, if there will be no recertification or lease renewal for a tenant during the first year after the rule takes effect, through other means.
(2) The grantee is responsible for ensuring that, for each tenant receiving HOPWA tenant-based rental assistance, the owner or manager of the tenant's housing unit commits to provide the notice of occupancy rights and certification form described in 24 CFR 5.2005 with any notification of eviction
(e)
(f)
42 U.S.C. 11371
(a) * * *
(7) If a program participant receiving short- or medium-term rental assistance under § 576.106 meets the conditions for an emergency transfer under 24 CFR 5.2005(e), ESG funds may be used to pay amounts owed for breaking a lease to effect an emergency transfer. These costs are not subject to the 24-month limit on rental assistance under § 576.106.
(e)
(g)
(e) * * *
(3) * * *
(vi) Policies and procedures for determining and prioritizing which eligible families and individuals will receive homelessness prevention assistance and which eligible families and individuals will receive rapid re-housing assistance (these policies must include the emergency transfer priority required under § 576.409);
(a)
(b)
(1) The recipient or subrecipient that administers the rental assistance for the purposes of 24 CFR 5.2005(e);
(2) The housing owner for the purposes of 24 CFR 5.2005(d)(1), (d)(3), and (d)(4) and 5.2009(a);
(3) The housing owner and the recipient or subrecipient that administers the rental assistance for the purposes of 24 CFR 5.2005(d)(2); and
(4) The housing owner and the recipient or subrecipient that administers the rental assistance for the purposes of 24 CFR 5.2007. However, the recipient or subrecipient may limit documentation requests under 24 CFR 5.2007 to only the recipient or subrecipient, provided that:
(i) This limitation is made clear in both the notice described under 24 CFR 5.2005(a)(1) and the rental assistance agreement;
(ii) The entity designated to receive documentation requests determines whether the program participant is entitled to protection under VAWA and immediately advise the program participant of the determination; and
(iii) If the program participant is entitled to protection, the entity designated to receive documentation requests must notify the owner in writing that the program participant is entitled to protection under VAWA and work with the owner on the program participant's behalf. Any further sharing or disclosure of the program participant's information will be subject to the requirements in 24 CFR 5.2007.
(c)
(1) When an individual or family is denied ESG rental assistance;
(2) When an individual or family's application for a unit receiving project-based rental assistance is denied;
(3) When a program participant begins receiving ESG rental assistance;
(4) When a program participant is notified of termination of ESG rental assistance; and
(5) When a program participant receives notification of eviction.
(d)
(i) The state as a whole;
(ii) Each area within the state that is covered by a Continuum of Care; or
(iii) Each subrecipient that administers ESG rental assistance.
(2) Once the applicable plan is developed in accordance with this section, the recipient and each subrecipient that administers ESG rental assistance must implement the plan in accordance with 24 CFR 5.2005(e).
(3) Each emergency transfer plan must meet the requirements in 24 CFR 5.2005(e) and include the following program requirements:
(i) For families living in units receiving project-based rental assistance (assisted units), the required policies must provide that if a program participant qualifies for an emergency transfer, but a safe unit is not immediately available for an internal emergency transfer, that program participant shall have priority over all other applicants for tenant-based rental assistance, utility assistance, and units for which project-based rental assistance is provided.
(ii) For families receiving tenant-based rental assistance, the required policies must specify what will happen with respect to the non-transferring family member(s), if the family separates in order to effect an emergency transfer.
(e)
(1) When a family receiving tenant-based rental assistance separates under 24 CFR 5.2009(a), the family's tenant-based rental assistance and utility assistance, if any, shall continue for the family member(s) who are not evicted or removed.
(2) If a family living in a unit receiving project-based rental assistance separates under 24 CFR 5.2009(a), the family member(s) who are not evicted or removed can remain in the assisted unit without interruption to the rental assistance or utility assistance provided for the unit.
(f)
(1) No individual or family may be denied admission to or removed from the emergency shelter on the basis or as a direct result of the fact that the individual or family is or has been a victim of domestic violence, dating violence, sexual assault, or stalking, if the individual or family otherwise qualifies for admission or occupancy.
(2) The terms “affiliated individual,” “dating violence,” “domestic violence,” “sexual assault,” and “stalking” are defined in 24 CFR 5.2003.
(s)
(5) Data on emergency transfers requested under § 576.409, pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of such requests.
42 U.S.C. 11371
(a) * * *
(9) * * *
(ii) Policies and procedures for determining and prioritizing which eligible individuals and families will receive transitional housing assistance (these policies must include the emergency transfer priority required under § 578.99(j)(8));
(iii) Policies and procedures for determining and prioritizing which eligible individuals and families will receive rapid rehousing assistance (these policies must include the emergency transfer priority required under § 578.99(j)(8));
(v) Policies and procedures for determining and prioritizing which eligible individuals and families will receive permanent supportive housing assistance (these policies must include the emergency transfer priority required under § 578.99(j)(8)); and
(d)
(m)
(j)
(j)
(2)
(i) The owner or landlord, which may be the recipient or subrecipient, for purposes of 24 CFR 5.2005(d)(1) and 5.2009(a);
(ii) The recipient, subrecipient, and owner or landlord for purposes of 24 CFR 5.2005(d)(2) through (d)(4); and
(iii) The recipient, subrecipient, and owner or landlord for purposes of 24 CFR 5.2007. However, the recipient or subrecipient may limit documentation requests under § 5.2007 to only the recipient or subrecipient, provided that:
(i) This limitation is made clear in both the notice described under 24 CFR 5.2005(a)(1) and the rental assistance agreement;
(ii) The entity designated to receive documentation requests determines whether the program participant is entitled to protection under VAWA and immediately advise the program participant of the determination; and
(iii) If the program participant is entitled to protection, the entity designated to receive documentation requests must notify the owner in writing that the program participant is entitled to protection under VAWA and work with the owner on the program participant's behalf. Any further sharing or disclosure of the program participant's information will be subject to the requirements in 24 CFR 5.2007.
(3)
(4)
(A) When an individual or family is denied permanent housing or transitional housing;
(B) When a program participant is admitted to permanent housing or transitional housing;
(C) When a program participant receives notification of eviction; and
(D) When a program participant is notified of termination of assistance.
(ii) When grant funds are used for rental assistance, the recipient or subrecipient must ensure that the owner or manager of the housing provides the notice and certification form described in 24 CFR 5.2005(a) to the program participant with any notification of eviction. This commitment and the confidentiality requirements under 24 CFR 5.2007(c) must be set forth in a contract with the owner or landlord.
(5)
(A) The requirement to comply with 24 CFR part 5, subpart L; and
(B) Where the owner or landlord of the housing will have a lease with a program participant, the requirement to include a lease provision that include all requirements that apply to tenants, the owner or the lease under 24 CFR part 5, subpart L, as supplemented by this part, including the prohibited bases for eviction and restrictions on construing lease terms under 24 CFR 5.2005(b) and (c).
(ii) The recipient or subrecipient must include in any lease, sublease, and occupancy agreement with the program participant a provision that include all requirements that apply to tenants, the owner or the lease under 24 CFR part 5, subpart L, as supplemented by this part, including the prohibited bases for eviction and restrictions on construing lease terms under 24 CFR 5.2005(b) and (c). The lease, sublease, and occupancy agreement may specify that the protections under 24 CFR part 5, subpart L, apply only during the period of assistance under the Continuum of Care Program. The period of assistance for housing where grant funds were used for acquisition, construction, or rehabilitation is 15 years from the date of initial occupancy or date of initial service provision.
(iii) Except for tenant-based rental assistance, recipients and subrecipients must require that any lease, sublease, or occupancy agreement with a program participant permits the program participant to terminate the lease, sublease, or occupancy agreement without penalty if the recipient or subrecipient determines that the program participant qualifies for an emergency transfer under the emergency transfer plan established under paragraph (j)(8) of this section.
(iv) For tenant-based rental assistance, the recipient or subrecipient must enter into a contract with the owner or landlord of the housing that:
(A) Requires the owner or landlord of the housing to comply with the provisions of 24 CFR part 5, subpart L; and
(B) Requires the owner or landlord of the housing to include a lease provision that include all requirements that apply to tenants, the owner or the lease under 24 CFR part 5, subpart L, as supplemented by this part, including the prohibited bases for eviction and restrictions on construing lease terms under 24 CFR 5.005(b) and (c). The lease may specify that the protections under 24 CFR part 5, subpart L, only apply while the program participant receives tenant-based rental assistance under the Continuum of Care Program.
(6)
(ii) For leases for tenant-based rental assistance existing prior to the effective date in paragraph (j)(2) of this section, recipients and subrecipients must enter into a contract under paragraph (j)(6)(iv) of this section before the next renewal of the lease.
(7)
(i) If a family who is receiving tenant-based rental assistance under this part separates under 24 CFR 5.2009(a), the family's tenant-based rental assistance and any utility assistance shall continue for the family member(s) who are not evicted or removed.
(ii) If a family living in permanent supportive housing separates under 24 CFR 5.2009(a), and the family's eligibility for the housing was based on the evicted individual's disability or chronically homeless status, the remaining tenants may stay in the project as provided under § 578.75(i)(2). Otherwise, if a family living in a project funded under this part separates under 24 CFR 5.2009(a), the remaining tenant(s) will be eligible to remain in the project.
(8)
(i) For families receiving tenant-based rental assistance, the plan must specify what will happen with respect to the non-transferring family member(s), if the family separates in order to effect an emergency transfer.
(ii) For families living in units that are otherwise assisted under this part (assisted units), the required policies must provide that for program participants who qualify for an emergency transfer but a safe unit is not immediately available for an internal emergency transfer, the individual or family shall have priority over all other applicants for rental assistance, transitional housing, and permanent supportive housing projects funded under this part, provided that: The individual or family meets all eligibility criteria required by Federal law or regulation or HUD NOFA; and the individual or family meets any additional criteria or preferences established in accordance with § 578.93(b)(1), (4), (6), or (7). The individual or family shall not be required to meet any other eligibility criteria or preferences for the project. The individual or family shall retain their original homeless or chronically homeless status for the purposes of the transfer.
(9)
(i) No individual may be denied admission to or removed from the safe haven on the basis or as a direct result of the fact that the individual is or has been a victim of domestic violence, dating violence, sexual assault, or stalking, if the individual otherwise qualifies for admission or occupancy.
(iii) The terms “affiliated individual,” “dating violence,” “domestic violence,” “sexual assault,” and “stalking” are defined in 24 CFR 5.2003.
(a) * * *
(6)
(ii) Data on emergency transfers requested under 24 CFR 5.2005(e) and § 578.99, pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of such requests.
42 U.S.C. 1437a, 1437c, 1437f, 3535(d), 12701, and 13611-13619.
(f)
(c) * * *
(5) In actions or potential actions to terminate tenancy, the owner shall follow 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
(a) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e).
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, covered housing providers have discretion to adopt new,
(c) In addition to following requirements in 24 CFR 5.2005(e), when a safe unit is not immediately available for a victim of domestic violence, dating violence, sexual assault, or stalking who qualifies for an emergency transfer, covered housing providers must:
(1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, covered housing providers must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), including data on the outcomes of such requests.
42 U.S.C. 1437f and 3535d.
(b) * * *
(a) The moderate rehabilitation program is subject to applicable Federal requirements in 24 CFR 5.105 and to the requirements for protection for victims of domestic violence, dating violence, sexual assault, or stalking in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, or stalking, covered housing providers have discretion to adopt and modify any existing admission preferences or transfer waitlist priorities for victims of domestic violence, dating violence, sexual assault, or stalking.
(c) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e), and when a safe unit is not immediately available for a victim of domestic violence, dating violence, sexual assault, and stalking who qualifies for an emergency transfer, covered housing providers must, at a minimum:
(1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, the covered housing provider must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of such requests.
(g) In actions or potential actions to terminate tenancy, the owner shall follow 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
(c)
(a) Participation in this program requires compliance with the Federal requirements set forth in 24 CFR 5.105, with the Americans with Disabilities Act (42 U.S.C. 12101
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, or stalking, covered housing providers have discretion to adopt and modify any existing admission preferences or transfer waitlist priorities for victims of domestic violence, dating violence, sexual assault, or stalking.
(c) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e), and when a safe unit is not immediately available for a victim of domestic violence, dating violence, sexual assault, and stalking who qualifies for an emergency transfer, covered housing providers must, at a minimum:
(1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, the covered housing provider must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), pertaining to victims of domestic violence, dating violence, sexual assault, or stalking, including data on the outcomes of such requests.
42 U.S.C. 1437a, 1437c, 1437f, 3535(d), and 13611-13619.
The provisions of 24 CFR 880.504 apply to this section, including reference at 24 CFR 880.504(f) to the requirements of 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking), subject to the requirements of § 883.105.
42 U.S.C. 1437a, 1437c, 1437f, 3535(d), and 13611-13619.
(c) In actions or potential actions to terminate tenancy, the owner shall follow 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
(f) The regulations in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply to this section.
(a) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e).
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, covered housing providers have discretion to adopt new, and modify any existing, admission preferences or transfer waitlist priorities.
(c) In addition to following requirements in 24 CFR 5.2005(e), when a safe unit is not immediately available for a victim of domestic violence, dating violence, sexual assault, or stalking who qualifies for an emergency transfer, covered housing providers must:
(1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, covered housing providers must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), including data on the outcomes of such requests.
42 U.S.C. 1437a, 1437c, 1437f, 3535(d), and 13611-13619.
Part 247 of this title (24 CFR part 247) applies to the termination of tenancy and eviction of a family assisted under this subpart. For cases involving termination of tenancy because of a failure to establish citizenship or eligible immigration status, the procedures of 24 CFR parts 247 and 5 shall apply. The provisions of 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence,
Subpart F of 24 CFR part 5 governs selection of tenants and occupancy requirements applicable under this subpart A of part 886. Subpart L of 24 CFR part 5 (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) applies to this section.
(a) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e).
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, covered housing providers have discretion to adopt new, and modify any existing, admission preferences or transfer waitlist priorities.
(c) In addition to following requirements in 24 CFR 5.2005(e), when a safe unit is not immediately available for a victim of domestic violence, dating violence, sexual assault, or stalking who qualifies for an emergency transfer, covered housing providers must: (1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, covered housing providers must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), including data on the outcomes of such requests.
Part 247 of this title (24 CFR part 247) applies to the termination of tenancy and eviction of a family assisted under this subpart. For cases involving termination of tenancy because of a failure to establish citizenship or eligible immigration status, the procedures of 24 CFR part 247 and 24 CFR part 5 shall apply. The provisions of 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply to this section. The provisions of 24 CFR part 5, subpart E, concerning certain assistance for mixed families (families whose members include those with eligible immigration status, and those without eligible immigration status) in lieu of termination of assistance, and concerning deferral of termination of assistance, also shall apply.
(f) The regulations of 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply to this section.
(a) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e).
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, covered housing providers have discretion to adopt new, and modify any existing, admission preferences or transfer waitlist priorities.
(c) In addition to following requirements in 24 CFR 5.2005(e), when a safe unit is not immediately available for a victim of domestic violence, dating violence, sexual assault, or stalking who qualifies for an emergency transfer, covered housing providers must:
(1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, covered housing providers must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), including data on the outcomes of such requests.
12 U.S.C. 1701q; 42 U.S.C. 1437f, 3535(d), and 8013.
(a) Covered housing providers must develop and implement an emergency transfer plan that meets the requirements in 24 CFR 5.2005(e).
(b) In order to facilitate emergency transfers for victims of domestic violence, dating violence, sexual assault, and stalking, covered housing providers have discretion to adopt new, and modify any existing, admission preferences or transfer waitlist priorities.
(c) In addition to following requirements in 24 CFR 5.2005(e), when a safe unit is not immediately available for a victim of domestic violence, dating
(1) Review the covered housing provider's existing inventory of units and determine when the next vacant unit may be available; and
(2) Provide a listing of nearby HUD subsidized rental properties, with or without preference for persons of domestic violence, dating violence, sexual assault, or stalking, and contact information for the local HUD field office.
(d) Each year, covered housing providers must submit to HUD data on all emergency transfers requested under 24 CFR 5.2005(e), including data on the outcomes of such requests.
(f) The regulations of 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply to this section.
(c)
(c) In actions or potential actions to terminate tenancy, the owner shall follow 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
42 U.S.C. 1437g, 42 U.S.C. 1437z-2, 42 U.S.C. 1437z-7, and 3535(d).
(g)
42 U.S.C. 1437a, 1437c, 1437d, 1437n, 1437z-3, and 3535(d).
(b) * * *
(d)
(b) * * *
(8) Protection for victims of domestic violence, dating violence, sexual assault, or stalking, 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
(c) * * *
(4) PHA tenant selection criteria are subject to 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking). In cases of requests for emergency transfers under VAWA, with the written consent of the victim of domestic violence, dating violence, sexual assault, or stalking, the receiving PHA may accept and use the prior covered housing provider's determination of eligibility and tenant screening and all related verification information, including form HUD 50058 (Family Report).
(b) * * *
(4)
42 U.S.C. 1437d and 3535(d).
(a) * * *
(1) * * *
(vi) HUD's regulations in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply.
(e) * * *
(9) To consider lease bifurcation, as provided in 24 CFR 5.2009, in circumstances involving domestic violence, dating violence, sexual assault, or stalking addressed in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking), provided that, if a PHA chooses to bifurcate a lease, no assistance will be given for an individual who does not meet public housing eligibility and 24 CFR 5.508(h)(2) applies to submission of evidence of citizenship or eligible immigration status.
42 U.S.C. 1437f and 3535d.
(e)
(a)
(d)
(b) * * *
(4)
(b) * * *
(4) In cases involving a victim of domestic violence, dating violence, sexual assault, or stalking, 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) applies.
(h) * * *
(4)
(a) * * *
(2) If the family break-up results from an occurrence of domestic violence, dating violence, sexual assault, or stalking as provided in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking), the PHA must ensure that the victim retains assistance.
(b) The factors to be considered in making this decision under the PHA policy may include:
(1) Whether the assistance should remain with family members remaining in the original assisted unit.
(2) The interest of minor children or of ill, elderly, or disabled family members.
(3) Whether family members are forced to leave the unit as a result of actual or threatened domestic violence, dating violence, sexual assault, or stalking.
(4) Whether any of the family members are receiving protection as victims of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L, and whether the abuser is still in the household.
(5) Other factors specified by the PHA.
(b)
(c) * * *
(4) Paragraph (c) of this section does not apply when the family or a member of the family is or has been the victim of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking), and the move is needed to protect the health or safety of the family or family member, or any family member who has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's request to move.
(b) * * *
(4) The family or a member of the family, is or has been the victim of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking), and the move is needed to protect the health or safety of the family or family member, or if any family member has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's request to move. A PHA may not terminate assistance if the family, with or without prior notification to the PHA, moves out of a unit in violation of the lease, if such move occurs to protect the health or safety of a family member who is or has been the victim of domestic violence, dating violence, sexual assault, or stalking and who reasonably believed he or she was threatened with imminent harm from further violence if he or she remained in the dwelling unit. However, any family member that has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's move or request to move is not required to believe that he or she was threatened with imminent harm from further violence if he or she remained in the dwelling unit.
(c) * * *
(2) * * *
(iii) The above policies do not apply when the family or a member of the family is or has been the victim of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L, and the move is needed to protect the health or safety of the family or family member, or any family member has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's request to move.
(b) * * *
(1) * * * The fact that an applicant is or has been a victim of domestic violence, dating violence, sexual assault, or stalking is not an appropriate basis for denial of tenancy if the applicant otherwise qualifies for tenancy.
(e)
(l)
(c) * * *
(2) * * *
(v)
(e) The requirements in 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) apply to this section.
(a) * * *
(2) The PHA may not commence continued tenant-based assistance for occupancy of the new unit so long as any family member owns any title or other interest in the prior home.
(3) The PHA may establish policies that prohibit more than one move by the family during any one-year period. However, these policies do not apply when the family or a member of the family is or has been the victim of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L, and the move is needed to protect the health or safety of the family or family member, or any family member has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's request to move.
42 U.S.C. 1437f and 3535(d).
(b) * * *
(a) * * *
(3) The protections for victims of domestic violence, dating violence, sexual assault, or stalking in 24 CFR part 5, subpart L, apply to admission to the project-based program.
(a) * * *
(4) The owner must comply with 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking).
(c) The protections for victims of domestic violence, dating violence, sexual assault, or stalking in 24 CFR part 5, subpart L, apply to tenant screening.
(d) The protections for victims of domestic violence, dating violence, sexual assault, or stalking in 24 CFR part 5, subpart L, apply to tenant screening.
(a) * * * 24 CFR part 5, subpart L (Protection for Victims of Domestic Violence, Dating Violence, Sexual Assault, or Stalking) applies to this part.
(c) * * *
(1) The above policies do not apply when the family or a member of the family is or has been the victim of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L, and the move is needed to protect the health or safety of the family or family member, or any family member has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's request to move. A PHA may not terminate assistance if the family, with or without prior notification to the PHA, moves out of a unit in violation of the lease, if such move occurs to protect the health or safety of a family member who is or has been the victim of domestic violence, dating violence, sexual assault, or stalking and who reasonably believed he or she was threatened with imminent harm from further violence if he or she remained in the dwelling unit, or any family member has been the victim of a sexual assault that occurred on the premises during the 90-calendar-day period preceding the family's request to move.
(2) If a family breaks up as a result of an occurrence of domestic violence, dating violence, sexual assault, or stalking, as provided in 24 CFR part 5, subpart L, the PHA may offer the victim the opportunity for continued tenant-based rental assistance.
The following appendices will not appear in the Code of Federal Regulations.
The Violence Against Women Act (VAWA) provides protections for victims of domestic violence, dating violence, sexual assault, or stalking. VAWA protections are not only available to women, but are available equally to all individuals regardless of sex, gender identity, or sexual orientation.
If you otherwise qualify for assistance under [
If you are receiving assistance under [
Also, if you or an affiliated individual of yours is or has been the victim of domestic violence, dating violence, sexual assault, or stalking by a member of your household or any guest, you may not be denied rental assistance or occupancy rights under [
Affiliated individual means your spouse, parent, brother, sister, or child, or a person to whom you stand in the place of a parent or guardian (for example, the affiliated individual is in your care, custody, or control); or any individual, tenant, or lawful occupant living in your household.
HP may divide (bifurcate) your lease in order to evict the individual or terminate the assistance of the individual who has engaged in criminal activity (the abuser or perpetrator) directly relating to domestic violence, dating violence, sexual assault, or stalking.
If HP chooses to remove the abuser or perpetrator, HP may not take away the rights of eligible tenants to the unit or otherwise punish the remaining tenants. If the evicted abuser or perpetrator was the sole tenant to have established eligibility for assistance under the program, HP must allow the tenant who is or has been a victim and other household members to remain in the unit for a period of time, in order to establish eligibility under the program or under another HUD housing program covered by VAWA, or, find alternative housing.
In removing the abuser or perpetrator from the household, HP must follow Federal, State, and local eviction procedures. In order to divide a lease, HP may, but is not required to, ask you for documentation or certification of the incidences of domestic violence, dating violence, sexual assault, or stalking.
Upon your request, HP may permit you to move to another unit, subject to the availability of other units, and still keep your assistance. In order to approve a request, HP may ask you to provide documentation that you are requesting to move because of an incidence of domestic violence, dating violence, sexual assault, or stalking. If the request is a request for emergency transfer, the housing provider may ask you to submit a written request or fill out a form where you certify that you meet the criteria for an emergency transfer under VAWA. The criteria are:
HP will keep confidential requests for emergency transfers by victims of domestic violence, dating violence, sexual assault, or stalking, and the location of any move by such victims and their families.
HP's emergency transfer plan provides further information on emergency transfers, and HP must make a copy of its emergency transfer plan available to you if you ask to see it.
HP can, but is not required to, ask you to provide documentation to “certify” that you are or have been a victim of domestic violence, dating violence, sexual assault, or stalking. Such request from HP must be in writing, and HP must give you at least 14 business days (Saturdays, Sundays, and Federal holidays do not count) from the day you receive the request to provide the documentation. HP may, but does not have to, extend the deadline for the submission of documentation upon your request.
You can provide one of the following to HP as documentation. It is your choice which of the following to submit if HP asks you to provide documentation that you are or have been a victim of domestic violence, dating violence, sexual assault, or stalking.
• A complete HUD-approved certification form given to you by HP with this notice, that documents an incident of domestic violence, dating violence, sexual assault, or stalking. The form will ask for your name, the date, time, and location of the incident of domestic violence, dating violence, sexual assault, or stalking, and a description of the incident. The certification form provides for including the name of the abuser or perpetrator if the name of the abuser or perpetrator is known and is safe to provide.
• A record of a Federal, State, tribal, territorial, or local law enforcement agency, court, or administrative agency that documents the incident of domestic violence, dating violence, sexual assault, or stalking. Examples of such records include police reports, protective orders, and restraining orders, among others.
• A statement, which you must sign, along with the signature of an employee, agent, or volunteer of a victim service provider, an attorney, a medical professional or a mental health professional (collectively, “professional”) from whom you sought assistance in addressing domestic violence, dating violence, sexual assault, or stalking, or the effects of abuse, and with the professional selected by you attesting under penalty of perjury that he or she believes that the incident or incidents of domestic violence, dating violence, sexual assault, or stalking are grounds for protection.
• Any other statement or evidence that HP has agreed to accept.
If you fail or refuse to provide one of these documents within the 14 business days, HP does not have to provide you with the protections contained in this notice.
If HP receives conflicting evidence that an incident of domestic violence, dating
HP must keep confidential any information you provide related to the exercise of your rights under VAWA, including the fact that you are exercising your rights under VAWA.
HP must not allow any individual administering assistance or other services on behalf of HP (for example, employees and contractors) to have access to confidential information unless for reasons that specifically call for these individuals to have access to this information under applicable Federal, State, or local law.
HP must not enter your information into any shared database or disclose your information to any other entity or individual. HP, however, may disclose the information provided if:
• You give written permission to HP to release the information on a time limited basis.
• HP needs to use the information in an eviction or termination proceeding, such as to evict your abuser or perpetrator or terminate your abuser or perpetrator from assistance under this program.
• A law requires HP or your landlord to release the information.
VAWA does not limit HP's duty to honor court orders about access to or control of the property. This includes orders issued to protect a victim and orders dividing property among household members in cases where a family breaks up.
You can be evicted and your assistance can be terminated for serious or repeated lease violations that are not related to domestic violence, dating violence, sexual assault, or stalking committed against you. However, HP cannot hold tenants who have been victims of domestic violence, dating violence, sexual assault, or stalking to a more demanding set of rules than it applies to tenants who have not been victims of domestic violence, dating violence, sexual assault, or stalking.
The protections described in this notice might not apply, and you could be evicted and your assistance terminated, if HP can demonstrate that not evicting you or terminating your assistance would present a real physical danger that:
1) Would occur within an immediate time frame, and
2) Could result in death or serious bodily harm to other tenants or those who work on the property.
If HP can demonstrate the above, HP should only terminate your assistance or evict you if there are no other actions that could be taken to reduce or eliminate the threat.
VAWA does not replace any Federal, State, or local law that provides greater protection for victims of domestic violence, dating violence, sexual assault, or stalking. You may be entitled to additional housing protections for victims of domestic violence, dating violence, sexual assault, or stalking under other Federal laws, as well as under State and local laws.
You may report a covered housing provider's violations of these rights and seek additional assistance, if needed, by contacting or filing a complaint with
You may view a copy of HUD's final VAWA rule at
Additionally, HP must make a copy of HUD's VAWA regulations available to you if you ask to see them.
For questions regarding VAWA, please contact
For help regarding an abusive relationship, you may call the National Domestic Violence Hotline at 1-800-799-7233 or, for persons with hearing impairments, 1-800-787-3224 (TTY). You may also contact
For tenants who are or have been victims of stalking seeking help may visit the National Center for Victims of Crime's Stalking Resource Center at
For help regarding sexual assault, you may contact
Victims of stalking seeking help may contact
This plan identifies tenants who are eligible for an emergency transfer, the documentation needed to request an emergency transfer, confidentiality protections, how an emergency transfer may occur, and guidance to tenants on safety and security. This plan is based on a model emergency transfer plan published by the U.S. Department of Housing and Urban Development (HUD), the Federal agency that oversees that
A tenant who is a victim of domestic violence, dating violence, sexual assault, or stalking, as provided in HUD's regulations at 24 CFR part 5, subpart L is eligible for an emergency transfer, if: The tenant reasonably believes that there is a threat of imminent harm from further violence if the tenant remains within the same unit. If the tenant is a victim of sexual assault, the tenant may also be eligible to transfer if the sexual assault occurred on the premises within the 90-calendar-day period preceding a request for an emergency transfer.
A tenant requesting an emergency transfer must expressly request the transfer in accordance with the procedures described in this plan.
Tenants who are not in good standing may still request an emergency transfer if they meet the eligibility requirements in this section.
To request an emergency transfer, the tenant shall notify HP's management office and submit a written request for a transfer to
1. A statement expressing that the tenant reasonably believes that there is a threat of imminent harm from further violence if the tenant were to remain in the same dwelling unit assisted under HP's program; OR
2. A statement that the tenant was a sexual assault victim and that the sexual assault occurred on the premises during the 90-calendar-day period preceding the tenant's request for an emergency transfer.
HP will keep confidential any information that the tenant submits in requesting an emergency transfer, and information about the emergency transfer, unless the tenant gives HP written permission to release the information on a time limited basis, or disclosure of the information is required by law or required for use in an eviction proceeding or hearing regarding termination of assistance from the covered program. This includes keeping confidential the new location of the dwelling unit of the tenant, if one is provided, from the person(s) that committed an act(s) of domestic violence, dating violence, sexual assault, or stalking against the tenant. See the Notice of Occupancy Rights under the Violence Against Women Act For All Tenants for more information about HP's responsibility to maintain the confidentiality of information related to incidents of domestic violence, dating violence, sexual assault, or stalking.
HP cannot guarantee that a transfer request will be approved or how long it will take to process a transfer request. HP will, however, act as quickly as possible to move a tenant who is a victim of domestic violence, dating violence, sexual assault, or stalking to another unit, subject to availability and safety of a unit. If a tenant reasonably believes a proposed transfer would not be safe, the tenant may request a transfer to a different unit. If a unit is available, the transferred tenant must agree to abide by the terms and conditions that govern occupancy in the unit to which the tenant has been transferred. HP may be unable to transfer a tenant to a particular unit if the tenant has not or cannot establish eligibility for that unit.
If HP has no safe and available units for which a tenant who needs an emergency is eligible, HP will assist the tenant in identifying other housing providers who may have safe and available units to which the tenant could move. At the tenant's request, HP will also assist tenants in contacting the local organizations offering assistance to victims of domestic violence, dating violence, sexual assault, or stalking that are attached to this plan.
Pending processing of the transfer and the actual transfer, if it is approved and occurs, the tenant is urged to take all reasonable precautions to be safe.
Tenants who are or have been victims of domestic violence are encouraged to contact the National Domestic Violence Hotline at 1-800-799-7233, or a local domestic violence shelter, for assistance in creating a safety plan. For persons with hearing impairments, that hotline can be accessed by calling 1-800-787-3224 (TTY).
Tenants who have been victims of sexual assault may call the Rape, Abuse & Incest National Network's National Sexual Assault Hotline at 800-656-HOPE, or visit the online hotline at
Tenants who are or have been victims of stalking seeking help may visit the National Center for Victims of Crime's Stalking Resource Center at
Environmental Protection Agency (EPA).
Proposed rule.
In this action, the Environmental Protection Agency (EPA) is proposing to update both its renewable fuels and other fuels regulations to reflect changes in the marketplace and to promote the growing use of both ethanol fuels (conventional and advanced) and non-ethanol advanced and cellulosic biofuels. The EPA is proposing to make several changes to the Renewable Fuel Standard (RFS) program regulations that would align them with recent developments in the marketplace to increase production of cellulosic and other advanced biofuels. There are several companies that have developed renewable fuel production technologies that produce a “biointermediate” at one facility that is then processed into renewable fuel at another facility, and we are proposing regulatory changes to allow fuels produced through such methods to qualify under existing approved renewable fuel production pathways. This action also proposes to update our fuel regulations by defining fuel blends containing 16 to 83 volume percent ethanol as ethanol flex fuel (EFF) and to no longer treat fuel blends containing 16 to 50 volume percent ethanol as gasoline. The EPA is proposing environmentally protective fuel quality specifications for EFF that are consistent with those already in place for gasoline. In this action we are also proposing new pathways for cellulosic biofuel produced from short-rotation trees and for renewable diesel and biodiesel produced from non-cellulosic portions of separated food waste. We are also proposing to add new registration, recordkeeping, and reporting requirements for facilities using carbon capture and storage if we were to approve the use of this technology in future assessments of proposed pathways for producing qualifying renewable fuel. We are also seeking comment on how best to implement and/or revise the RFS regulations pertaining to the generation of RINs for renewable electricity used as transportation fuel. Finally, we are proposing a number of other regulatory changes, clarifications, and technical corrections to the RFS program and other fuels regulations.
Submit your comments, identified by Docket ID No. EPA-HQ-OAR-2016-0041, at
Julia MacAllister, Assessment and Standards Division, Office of Transportation and Air Quality, Environmental Protection Agency, 2000 Traverwood Drive, Ann Arbor, MI 48105; telephone number: (734) 214-4131; email address:
A red-line version of the regulatory language that incorporates the proposed changes in this action is available in the docket for this action (Docket ID No. EPA-HQ-OAR-2016-0041).
The Environmental Protection Agency (EPA) is committed to taking steps to reduce emissions of greenhouse gases (GHGs). This commitment is based on several charges given to the EPA, such as the Climate Action Plan announced by President Obama in June 2013,
The fundamental objective of the RFS program under the CAA is to increase the use of renewable fuels in the U.S. transportation system every year through at least 2022. These fuels include corn starch ethanol, the predominant biofuel in use to date, but Congress envisioned the growth beyond 2015 to come from cellulosic and other advanced biofuels that are required to have lower GHG emissions on a lifecycle basis than conventional (non-advanced) biofuels.
Nevertheless, real-world limitations, such as the slower than predicted development of the cellulosic biofuel industry, less growth in gasoline use than was expected when Congress enacted the RFS provisions in 2007, and the “E10 blendwall,”
In order to continue the progress made in promoting the use of renewable fuels in the transportation sector, we believe it is important to take steps to remove potential barriers to their production, distribution, and consumption where such actions make sense. To this end, we have identified a number of areas where adjustments to
We are also proposing a number of other changes to the RFS regulations and other fuel regulations to streamline them, provide clarifications, and make technical corrections.
Since the RFS2 program was finalized in 2010, we have been made increasingly aware of renewable fuel producers that would like to process fuel at more than one facility. In some cases, it may be preferable for economic or practical reasons for renewable biomass to be subjected to substantial pre-processing at one facility before being sent to a different facility where it is converted into renewable fuel. For example, renewable biomass may be converted into a proto-renewable fuel (such as a bio-oil) at one facility that requires some additional processing at a different facility before it can be used as transportation fuel. These production methodologies have the potential to lower the cost of using cellulosic and other feedstocks for the production of renewable fuels by reducing the storage and transportation costs associated with feedstock handling—especially for cellulosic biomass. Thus, we believe that such technologies hold considerable promise for the future growth in production of the cellulosic biofuels required under the RFS program. However, we did not envision significant fuel production operations occurring over multiple facilities in drafting the existing regulations, and regulatory changes are necessary to both generally allow such practices, and to provide the necessary registration, reporting, and recordkeeping requirements that will facilitate appropriate oversight by the EPA.
We believe that increasing use of these “biointermediates” will likely provide an important component of the growth in renewable fuel production in the future, particularly for advanced and cellulosic biofuels. We are proposing changes in the RFS regulations to clearly specify requirements that apply when renewable fuel is produced through sequential operations at more than one facility. These changes center around the production, transfer, and use of biointermediates and the creation of new regulatory requirements related to registration, recordkeeping, and reporting for facilities producing or using a biointermediate for renewable fuel production. The new requirements on the biointermediate producer would be similar to those already required for renewable fuel producers.
In the Tier 3 Motor Vehicle Emission and Fuel Standards (“Tier 3”) final rule, the EPA finalized new standards for passenger vehicles, including flexible fuel vehicles (FFVs), and more stringent gasoline sulfur standards to enable those standards to be achieved.
FFVs are vehicles that are designed to operate on any gasoline-ethanol mixture between pure gasoline (E0) and 85 percent denatured ethanol (E85). FFVs have been manufactured and introduced into commerce since 1996, and represent more than 6 percent of the current vehicle fleet and approximately 25 percent of new light-duty vehicles produced in 2014. Given that FFVs tend to be newer vehicles that are driven more than older vehicles, FFVs account for nearly 8 percent of all light-duty vehicle miles traveled.
By broadening the range of blendstocks that can be used to produce EFF, and thereby providing the opportunity for the production of lower cost EFF, this proposal encourages increased use of EFF. We anticipate that the volume of higher-level ethanol blends used in FFVs will increase substantially as the volume requirements of the RFS increase, and this proposal is intended to support this growth. Public and private initiatives are also currently underway to expand the use of blender pumps that dispense a variety of gasoline-ethanol blends for use in FFVs.
It is important to note that the focus and application of this proposal is on the requirements for fuels used in FFVs. However, we are also separately proposing streamlined compliance provisions regarding the production of E15 at blender pumps. Apart from these proposed streamlined provisions for the production of gasoline at blender pumps, the EPA's existing fuel regulations, including waiver provisions, would continue to apply for fuels used in gasoline- and diesel-powered vehicles. For example, the EPA would need to approve a new waiver request for E16 or other higher-level ethanol blends to be used in gasoline vehicles.
In this action we are also proposing a number of amendments to the RFS regulations. First, the EPA is proposing registration, recordkeeping, and reporting requirements that we would use if we were to allow carbon capture and storage (CCS) as a lifecycle GHG emissions reduction technology in the context of the RFS program.
Second, we are proposing to approve new pathways for the production of cellulosic fuels using short-rotation hybrid poplar and willow trees as a feedstock. These new pathways would allow for ethanol and naphtha produced from these feedstocks to qualify for cellulosic biofuel (D-code 3) RINs, and for diesel, jet fuel, and heating oil produced from these feedstocks to qualify for cellulosic biomass-based diesel (D-code 7) RINs. As discussed in section VI of this preamble, our analysis shows that fuel produced from short-rotation hybrid poplar and willow trees using a variety of processing technologies meets the 60 percent GHG emissions reduction threshold needed to qualify for cellulosic biofuel (D-code 3) RINs and cellulosic biomass-based diesel (D-code 7) RINs.
Third, we are seeking comment on several potential approaches for the generation of RINs for electricity that is produced from biogas and used as a transportation fuel. The EPA has received a number of registration requests for approval under the existing RFS regulations and these requests envision generation of RINs by different types of entities in the renewable electricity production, distribution or use sectors, using different types of information to verify the use of renewable electricity as transportation fuel. Given the diversity of the registration requests submitted to date, and the necessity of avoiding the generation of multiple RINs for the same quantity of electricity, the approval of any one of these proposed systems may preclude in whole or in part the approval of others. As discussed in section VII of this preamble, the EPA seeks input on the approach to RIN generation for renewable electricity that would best further the goals of the RFS program, but does not propose a preferred approach.
We are also proposing to make several additional revisions to the RFS regulations, which include:
• Clarifying what corn oil may be used as a feedstock for existing renewable fuel production pathways and revising the definition of “corn oil extraction.”
• Approving new pathways for the production of renewable diesel and biodiesel from non-cellulosic portions of separated food waste.
• Expanding the current definition of heating oil to include fuels that are used to cool interior spaces of homes or buildings.
• Revising the requirements for separated food waste plans.
• Approving a new pathway for the production of cellulosic diesel, jet fuel, and heating oil from cellulosic biomass that is co-processed with petroleum.
• Revising the requirements for the generation of RINs for fuel made from vegetable oils.
• Requiring obligated parties to report the breakdown of gasoline, diesel, and heating oil production as part of their annual compliance reports.
• Establishing a cut-off date for the submission of registration requests related to new or expanded baseline volumes that are exempt from the GHG reduction thresholds.
• Allowing parties that blend renewable fuel to produce transportation fuel under a national security exemption (NSE) to delegate to an upstream party the Renewable Identification Number (RIN)-related responsibilities.
• Revising and clarifying the requirements for renewable fuel producers incident to the transfer of ownership of a registered renewable fuel production facility.
• Modifying the requirements for third-party engineers that perform engineering reviews for renewable fuel producers.
• Adding additional circumstances that may justify action by EPA to deactivate a company's RFS registration.
• Requiring biogas producers whose biogas is used to produce renewable electricity, compressed natural gas (CNG), or liquid natural gas (LNG) to register with the EPA.
• Consolidating the requirements for RIN retirement into a new section in the RFS regulations.
• Specifying what RIN transactional information and RFS compliance information that is submitted through EMTS is entitled to treatment as CBI, and that certain RIN-related information cannot be claimed as CBI when it is central to describing specified actions by the EPA (including decisions by the EPA on small refinery and small refiner hardship petitions), and EPA enforcement-related actions such as notices of violations and criminal indictments.
• Specifying the types of feedstocks that can be used at grandfathered facilities to produce qualifying renewable fuel that is exempt from the 20 percent lifecycle GHG reduction requirement.
• Removing the option for RIN-generating foreign producers to pay the required bond amount to the U.S. Treasury instead of obtaining a bond in the proper amount from a third-party surety agent.
• Addressing situations where a party is aware that renewable fuel it intends to transfer will be used for purposes other than as transportation fuel, heating oil, or jet fuel.
• Making numerous technical corrections that update addresses, references, and other minor edits.
Finally, we note that we may choose to finalize some or all of the amendments contained in this proposed rulemaking.
Entities potentially affected by this proposed rule are those involved with the production, distribution, and sale of transportation fuels, including gasoline and diesel fuel or renewable fuels such as ethanol, biodiesel, renewable diesel, and biogas. Potentially regulated categories include:
This table is not intended to be exhaustive, but rather provides a guide for readers regarding entities likely to be regulated by this action. This table lists the types of entities that the EPA is now aware could potentially be regulated by this action. Other types of entities not listed in the table could also be regulated. To determine whether your entity is regulated by this action, you should carefully examine the applicability criteria in the referenced regulations. If you have any questions regarding the applicability of this action to a particular entity, consult the person listed in the
In this action, the EPA is taking steps to bring our RFS and gasoline regulations more in line with marketplace changes in an effort to further advance the goals of the RFS program by facilitating the production and use of renewable fuels in the transportation sector. As discussed in section III of the preamble, we are proposing changes to the RFS regulations to generally allow the use of biointermediates in renewable fuel production, thereby facilitating the increased production of renewable fuels, including cellulosic and other advanced biofuels. As discussed in section IV of this preamble, we are proposing standards that will address the public health and welfare effects of EFF and its impact on emissions control devices on FFVs and FFV engines under CAA section 211(c). Our proposed provisions would support the increased production and use of higher-level ethanol blends by treating all E16-83 as EFF (instead of continuing to treat E16-50 as gasoline), implement new environmentally protective fuel quality specifications for EFF, and allow for the use of lower cost blendstocks in EFF, thereby advancing the goals of the RFS program by facilitating the increased use of ethanol in transportation fuel and, in particular, at levels beyond those associated with the use of E10 alone. Finally, as discussed in sections V, VI,
Statutory authority for this action comes from Clean Air Act sections 203-205, 208, 211, and 301.
Through the proposed provisions for EFF, biointermediates, and new renewable fuel production pathways, this action would provide significant regulatory flexibility, streamlined compliance provisions, and the opportunity for increased biofuel production at reduced cost. As we are primarily providing parties with new flexibilities to produce EFF or renewable fuel, we expect that parties would only elect to take advantage of these proposed flexibilities if the potential economic benefits outweigh the added cost. We expect that, in general, the cost savings associated with these new provisions would far outweigh any minor costs for demonstrating compliance. This proposal also contains minor additional requirements that would apply to some biofuel producers and distributors; however, the costs associated with these requirements are expected to be very small. A more detailed discussion of the economic impacts of this action can be found in section X of this preamble.
One of the goals of the RFS program is to reduce the amount of GHGs emitted as transportation fuel by increasing the amount of cellulosic and advanced biofuels consumed by on-road and offroad vehicles and engines. While the RFS program has had success in promoting the use of conventional biofuel (primarily corn ethanol) and advanced biofuels (primarily biodiesel), the production and use of cellulosic biofuels has noticeably lagged behind. As noted in the preamble to the final rule establishing RFS standards for 2014, 2015, and 2016,
The RFS registration, reporting, recordkeeping, and PTD requirements were designed with the general expectation that renewable biomass would be converted into renewable fuel at a single facility (
Sweetwater Energy's technology converts cellulosic biomass feedstocks to cellulosic sugars using a modular approach. They plan to build relatively small facilities near the bulk feedstock source and transport the concentrated sugars they produce to a larger facility where they will be converted into renewable fuels and chemicals. At this time, Sweetwater is not able to register to produce cellulosic biofuel due to their multiple-facility approach to renewable fuel production.
Ensyn's technology, known as Rapid Thermal Processing, involves the non-catalytic thermal conversion of woody biomass feedstocks to produce renewable chemicals, food additives, and heating oil at five commercial facilities in Wisconsin and Ontario, Canada. Ensyn registered its Ontario facility under the RFS program in 2014 and has generated cellulosic biomass-based diesel (D-code 7) RINs related to sales in the U.S. of its primary fuel product, known as renewable fuel oil (RFO), as a replacement for heating oil. They also plan to sell the RFO to petroleum refineries as a feedstock that can be further processed to produce renewable gasoline and diesel if the use of biointermediates is approved by the EPA.
The EPA believes that the use of biointermediates to produce renewable fuels is a reasonable and positive development in this developing industry and holds considerable promise for the future growth in production of the cellulosic and advanced biofuels. While near-term production may be modest, significant potential for further growth in the long-term exists, as these technologies can lower the cost of using cellulosic and other feedstocks for the production of renewable fuels by reducing the storage and transportation costs associated with bulky feedstocks and taking advantage of existing ethanol and petroleum refinery assets to convert the biomass to renewable fuel. This makes biointermediate production and use an important component of the growth of the RFS program in the future, especially the growth of the cellulosic biofuel volumes.
However, scenarios involving the use of biointermediates to produce renewable fuel pose significant concerns for the EPA in terms of ensuring that the finished fuel was made with qualifying renewable biomass, through production processes corresponding with approved RIN-generating pathways, and in volumes corresponding to feedstocks used. Companies requesting to be allowed to use a biointermediate have asked the EPA to approve their production process and allow for RIN generation by the eventual renewable fuel producer. To address the EPA's concerns about the potential for RIN fraud, many companies also offered to be subject to oversight requirements more stringent than those in the current
In response to these requests, the EPA has stated that the existing RFS provisions are insufficient to generally allow RINs to be generated in situations wherein multiple facilities are involved in the conversion of renewable feedstocks into renewable fuel. We also stated that we believed that the most straightforward approach to address this issue was through the rulemaking process. This proposed rule begins that rulemaking process. As described further below, this proposal provides a set of requirements that will enable the production and use of biointermediates to make renewable fuel for which RINs can be generated. The EPA seeks comment on the proposed biointermediate regulatory program described below. We also seek comment from potential producers of biointermediates on the current status of operations, potential production volumes, timelines for production, and any other information that may help inform the EPA as to the expected use of biointermediates to produce renewable fuel in the future.
We are proposing to define a biointermediate as any renewable fuel feedstock material that meets all of the following criteria:
• It is derived from renewable biomass.
• It does not meet the definition of renewable fuel and RINs were not generated for it.
• It is produced at a facility that is registered with the EPA, but which is different than the facility at which it is used to produce renewable fuel.
• It is made from the feedstock and will be used to produce the renewable fuel in accordance with the process(es) listed in the approved pathway.
• It is processed in such a way that it is substantially altered from the feedstock listed in the approved pathway.
In addition, we are proposing that any feedstock listed in Table 1 to 40 CFR 80.1426 or in an approved pathway pursuant to 80 CFR 80.1416 is not a biointermediate, and that a mere “form change” to renewable biomass does not create a biointermediate. We note that in many existing traditional operations, there is some degree of physical pre-processing of renewable biomass to make feedstocks listed in Table 1 to 40 CFR 80.1426 and in pathways approved pursuant to 40 CFR 80.1416. Such pre-processing may occur under the existing regulations at a different facility than the facility producing renewable fuel. For example, the planted crop soy beans are crushed to make the soy bean oil feedstock listed in pathways F and H in Table 1 to 40 CFR 80.1426, and such crushing often occurs at locations other than the renewable fuel production facility. Since soy oil is a feedstock listed in Table 1, the proposed definition of biointermediate would not include soy bean oil notwithstanding this crushing activity. For feedstocks listed in Table 1 to 40 CFR 80.1426, we do not believe that the additional proposed regulatory requirements for processes using a biointermediate are necessary to ensure that RINs are only generated for qualifying fuel. In addition, certain processing of feedstocks would not result in sufficient alteration to result in a biointermediate. Some examples of processing involving form changes that would not result in the production of a biointermediate include the following:
• Chopping biomass into small pieces, pressing it, or grinding it into powder.
• Filtering out suspended solids from recycled cooking and trap grease.
• Degumming vegetable oils.
• Drying wet biomass.
• Adding water to biomass to produce a slurry.
We are proposing that renewable biomass subject to these types of processing would be excluded from the definition of a biointermediate and, therefore, that such activities can be conducted at a different facility than the facility producing renewable fuel without triggering the need for the additional recordkeeping, reporting, and registration requirements being proposed for producers of biointermediates. Similarly, the separation activities described in 40 CFR 80.1426(f)(5) that are required for yard waste, food waste, or municipal solid waste (MSW) to be considered renewable biomass would not be viewed as creating a biointermediate. Finally, as is generally the case for all feedstocks used in renewable fuel production, the presence of incidental,
We note that based on our proposed definition of biointermediate, undenatured ethanol that is subsequently denatured at a separate facility would be considered a biointermediate. Under the current RFS provisions, ethanol does not become a renewable fuel until a producer adds denaturant in accordance with the requirements of the Alcohol and Tobacco Tax and Trade Bureau of the U.S. Treasury Department at 27 CFR parts 19-21. Only after a renewable fuel producer has denatured the ethanol can they generate RINs for it; the domestic producer of the undenatured ethanol is not currently subject to any RFS requirements. Under the proposed biointermediate definition, the producer of the undenatured ethanol would be required to register as a biointermediate producer and the party that denatured the ethanol would be required to register as a renewable fuel producer.
Unlike domestic producers, foreign ethanol producers typically do not denature their ethanol product, but instead rely on importers to add denaturant and generate RINs for the finished renewable fuel. Reflecting this practice, the current RFS regulations require that foreign ethanol producers register with the EPA similar to renewable fuel producers (
The EPA has evaluated whether any revisions would need to be made to Table 1 to 40 CFR 80.1426 if biointermediates were generally allowed to be used. Table 1 lists the generally-applicable pathways for the production of non-grandfathered renewable fuel. The pathways include D codes, which correspond to the RFS fuel category for which the finished renewable fuel qualifies (
Under the RFS program, the EPA must assess lifecycle GHG emissions to determine which fuel pathways meet the GHG reduction thresholds for the four required renewable fuel categories. For the 2010 RFS2 final rule, the EPA assessed the lifecycle GHG emissions of multiple renewable fuel pathways and classified pathways based on these GHG thresholds, as compared to the 2005 statutory baseline.
The pathways consist of fuel type, feedstock, and production process requirements. GHG emissions are assessed at all points throughout the lifecycle pathway. For instance, emissions associated with sowing and harvesting of feedstocks and in the production, distribution, and use of the renewable fuel are examples of what are accounted for in the GHG assessment. A full accounting of emissions is then compared with the petroleum baseline emissions for the conventional fuel being replaced. The lifecycle GHG emissions determination is one factor used to determine compliance with the RFS regulations.
There are currently over a dozen renewable fuel pathways with various types of feedstocks and production processes used, qualifying the pathways as either conventional (D-code 6), biomass-based diesel (D-code 4), advanced (D-code 5), or cellulosic (D-code 3). The EPA also created a cellulosic biomass-based diesel (D-code 7) category for fuels that can qualify as both biomass-based diesel and cellulosic biofuel. The lifecycle GHG emissions determinations for these different pathways were based on the assumption that the feedstocks listed would be converted to renewable fuel at a single facility.
If the EPA were to generally allow the use of biointermediates, one main difference in GHG emissions would potentially be the additional emissions associated with transporting the biointermediate from the biointermediate production facility to the renewable fuel production facility. However, it is expected that overall transportation emissions would decrease, since bulk biomass would typically be transported a shorter distance to the biointermediate production facility. For example, the lifecycle GHG assessment for existing pathways already accounts for feedstock and fuel transportation, so if a biointermediate facility is located close to feedstock production it would reduce unprocessed feedstock transport emissions. Biointermediate transport emissions would be added but typically biointermediates are more energy dense than unprocessed feedstock and would have lower GHG emissions associated with transport.
Furthermore, lifecycle GHG emissions could also be reduced with a biointermediate pathway vs. a single facility pathway by allowing upstream and downstream processing to be better optimized for the production of the biointermediate and the fuel respectively. Also, the biointermediate pathway could offer the opportunity to leverage greater economies of scale for improved efficiency when processing or refining biointermediates into finished fuel products also reducing lifecycle GHG emissions.
Based on these considerations, the EPA believes the GHG emissions associated with producing renewable fuel from a biointermediate will be the same or less than the GHG emissions associated with producing renewable fuel from feedstocks listed in Table 1 to 40 CFR 80.1426 at a single facility. Therefore, the original lifecycle analyses for the renewable fuel pathways listed in Table 1 to 40 CFR 80.1426 support allowing a biointermediate to be used to produce renewable fuel for the existing pathways. Once the regulatory change to allow the use of biointermediates is final, all of the pathways currently applicable to renewable fuel under Table 1 to 40 CFR 80.1426 will allow for the use of biointermediates. This assumes, of course, that the same conversion processes that are specified for the pathway are used, even if they occur at more than one facility. Of course, fuel cannot be made from a biointermediate for a pathway that is not listed in Table 1 to 40 CFR 80.1426 or otherwise approved by the EPA; parties seeking to use a new pathway (with or without the production and use of a biointermediate) must petition the EPA for a new pathway approval pursuant to 40 CFR 80.1416.
We are proposing that the approved pathways in Table 1 to 40 CFR 80.1426 (as well as those approved in response to petitions submitted pursuant to 40 CFR 80.1416) would continue to identify the feedstocks and processes that are acceptable to make renewable fuel for the respective pathways; however, if this proposal were finalized, the processes specified could be conducted in more than one facility. Since biointermediates would be altered from the feedstocks listed in Table 1 to 40 CFR 80.1426, the renewable fuel producer would require sufficient information from the biointermediate producer to verify that the biointermediate is made from the feedstock listed in the approved pathway being used by the renewable fuel producer.
In general, we are proposing that from the perspective of a renewable fuel producer, a qualifying biointermediate would be treated as being equivalent to the renewable feedstock from which it was derived for purposes of identifying the appropriate RIN-generating pathway from Table 1 to 40 CFR 80.1426. However, there are several cases in which we believe this would be inappropriate. These cases would be those in which certain non-characteristic portions of a renewable feedstock were separated or extracted into a concentrated biointermediate that was inconsistent with the predominant constituents of the feedstock in the approved pathway. For instance, if oils or sugars were extracted (physically separated) from cellulosic feedstocks to produce a concentrated oil or sugar biointermediate, those oils or sugars would not be viewed as representing a cellulosic feedstock, as they would not contain cellulose, hemicellulose, or lignin and were not derived from cellulose, hemicellulose, or lignin.
We are not proposing to change the current system in which, with very few exceptions, only the renewable fuel producer would be permitted to generate RINs. This means that the party that produces renewable fuel from a biointermediate would generate RINs, rather than the producer of the biointermediate. We believe this approach would be the easiest to both implement and enforce, and would involve no disruption from current practices. If we were to allow for different points of RIN generation, it would add unnecessary complexity and difficulty to the program, and introduce an opportunity for fraudulent double-generation of RINs for the same volume of renewable fuel. Our proposal would not preclude renewable fuel producers from entering into contracts with biointermediate producers that would provide for transfer of some or all of the RIN value to the biointermediate producer, but for the purposes of RIN generation and assignment within the EPA Moderated Transaction System (EMTS), only the renewable fuel producer would be able to generate and assign the RIN (except to the extent that the regulations related to a particular pathway specifically provide otherwise).
We are not proposing to change the current flexibility for RIN generation for renewable electricity and CNG/LNG made from biogas. Although we proposed to limit the parties allowed to generate such RINs in the final Pathways II rule, we deferred finalizing that aspect of our proposal, pending further consideration.
In the 2010 RFS2 final rule, the EPA promulgated requirements for the generation of RINs for renewable fuel co-processed with petroleum-based fuels, and provided two methods for determining the renewable content of co-processed fuels: (1) Mass balance; or (2) Using Methods B or C of ASTM D6866 C-14 testing.
We recognize that co-processing configurations are highly complex and varied and that proposing Method B of ASTM D6866 as the only method to determine renewable content of co-processed fuels produced from biointermediate feedstocks may place a high cost on parties that generate RINs from co-processed fuels. One potential option would be to require Method B of ASTM D6866 as the default method for determining renewable content of co-processed partially renewable fuel produced from a biointermediate and allow parties to petition the EPA to use other methods for determining the renewable content based on the unique process of the company producing the co-processed fuel. In some cases an appropriately characterized mass balance approach may provide reasonable assurance that RINs are not being attributed to non-qualifying fuels (
We seek comment on whether only allowing Method B of ASTM D6866 for RIN generation for this situation is appropriate. We also seek comment on whether other methods should be allowed and if so what methods could produce similar accuracy and precision to Method B of ASTM D6866 for purposes of measuring renewable content in co-processed fuels. For any suggested methods, we request a thorough description of the method and data that helps establish the relative accuracy and precision of the method. Lastly, we seek comment on whether the EPA should allow parties to petition for the use of a company-specific method to determine the renewable content of co-processed partially-renewable fuel produced from a biointermediate.
Finally, due to the potential complexity involved in determining the validity of RINs generated for renewable fuel produced from a biointermediate, we are proposing that if the EPA determines that any of the RINs in any batch of renewable fuel produced from
We are proposing that the processing of a feedstock listed in an approved pathway into a biointermediate may only occur at a single facility before the biointermediate is transported to a renewable fuel production facility. Hence, there will only be two parties involved in the transformation of a feedstock listed in an approved pathway into renewable fuel, which will make it much more straightforward for the EPA to track and enforce. While it is possible that the production of certain biointermediates may require processing at multiple facilities in the future, most if not all of the inquiries that the EPA has received so far regarding biointermediates have only involved two facilities: One to produce the biointermediate and another to turn the biointermediate into renewable fuel. There are also numerous implementation and enforcement concerns associated with allowing more than one facility to be involved in the production of a given biointermediate, as each extra production step adds another layer of complexity and potential for fraud to occur. Thus, we are not proposing to allow for multiple facilities to be involved in the production of a biointermediate at this time.
We are proposing registration, reporting, recordkeeping, and PTD requirements for parties involved in the production of biointermediates, as well as modified requirements for renewable fuel producers using biointermediates to make renewable fuel. We are also proposing that biointermediate and renewable fuel producers would be liable for violation of these requirements.
In general, the renewable fuel producer is responsible for verifying and demonstrating that the renewable fuel they produce is derived from renewable biomass and was produced in accordance with an approved biofuel production pathway.
We are proposing to require that biointermediate producers register with the EPA by facility in a manner similar to renewable fuel producers. We are also proposing slight modifications to the registration requirements for renewable fuel producers that wish to use a biointermediate to produce renewable fuel. The registration information submitted by the biointermediate producer would include the submission of basic company information (
The EPA notes that although we intend to conduct a threshold review of registration materials prior to accepting
We seek comment on whether there are any additional registration requirements needed for biointermediate producers or renewable fuel producers to help ensure that the parties themselves and EPA enforcement personnel have available to them the information necessary to ensure the appropriate production and use of biointermediates.
We are proposing that biointermediate producers would submit quarterly reports that include feedstock and process information by batch, volume of the batch, and cellulosic and non-cellulosic content of the batch, as well as the specific renewable fuel facility where the batch of biointermediate was intended to be used for the production of renewable fuel. The biointermediate producer would also be required to designate each batch that is intended to be used as a renewable fuel feedstock, so that the biointermediates batches are directly linked to the renewable fuel batches produced from that biointermediate. The biointermediate producer would also be required to report the renewable content and adjusted cellulosic content of each biointermediate batch and certify that the renewable content of each biointermediate batch met the renewable biomass requirement. We are also proposing changes to the periodic reporting requirements for renewable fuel producers that use a biointermediate to help the EPA track that biointermediates are being used appropriately. These proposed reporting requirements would help the EPA monitor compliance concerning the production and use of biointermediates by directly linking the volume of biointermediate produced by a biointermediate producer with the volume of renewable fuel produced by a renewable fuel producer.
We are also proposing modifications to the EMTS reporting requirements for producers of renewable fuel to help track and ensure that biointermediates are used appropriately. Currently, feedstocks used to produce a renewable fuel are tracked on a per-batch basis in EMTS. Due to the similarity between the ways that biointermediates would be used and existing feedstocks are already being used, we are proposing that biointermediate use also be tracked through EMTS. In addition, aligning batches of RINs generated for renewable fuel with the biointermediate batches used to produce the fuel would help the EPA monitor that volumes of biointermediates are appropriately used to generate valid RINs. Therefore, we are proposing that renewable fuel producers specify in EMTS both the amount of biointermediate feedstock used to produce each batch of fuel, as well as the party from whom the biointermediate was produced, received, purchased, or procured. This is somewhat analogous to EMTS reporting requirements for RIN-generating importers of foreign renewable fuel. For example, in order to generate RINs for a volume of renewable fuel produced at a foreign renewable fuel facility, renewable fuel importers must identify in EMTS the foreign renewable fuel facility for each batch of imported renewable fuel for which they generate RINs, among other batch requirements.
These proposed changes to EMTS, while simple in concept, nevertheless will constitute a significant modification to the coding of the existing EMTS system, which will take time to develop and test to ensure adequate functionality. Therefore, we anticipate that if we finalize the proposed biointermediate provisions, we will delay the full tracking of biointermediates in EMTS, but not the periodic reporting requirements, until January 1, 2018, so that the changes to EMTS could reasonably be developed and tested. As discussed in more detail in section III.L of this preamble, biointermediate producers and renewable fuel producers using biointermediates would be permitted to meet interim implementation requirements pending EMTS modification. Parties would still be required to submit periodic reports outside of EMTS to help the EPA monitor compliance with biointermediate requirements.
We believe that these reporting requirements and tracking in EMTS would help the EPA monitor the generation of RINs for renewable fuel produced from a biointermediate, thereby reducing the potential for fraud and enhancing the integrity of the program. We seek comment on whether we should require any additional reporting requirements from biointermediate producers or renewable fuel producers.
We are proposing that biointermediate producers would have essentially the same feedstock and process-related recordkeeping requirements as those already in place for renewable fuel producers. Since the biointermediate producer would be a party between suppliers of feedstocks listed in Table 1 to 40 CFR 80.1426 and the renewable fuel producer, the biointermediate producer would need to maintain records related to the purchase of feedstocks used to produce the biointermediate. Biointermediate producers would also need to maintain appropriate records that demonstrate that feedstocks meet the definition of renewable biomass. Finally, biointermediate producers would need to keep records of any calculations the biointermediate producer used to determine the renewable or cellulosic content of the biointermediate, as applicable. This information would need to be conveyed to any renewable fuel producer that uses the biointermediate as part of the required PTDs. Renewable fuel producers would need to maintain these PTDs in addition to their current recordkeeping requirements. We seek comment on whether there are any additional records that should be kept by biointermediate producers or renewable fuel producers to accommodate the proposed use of biointermediates.
In order to help provide renewable fuel producers using biointermediates the information they need to ensure the validity of RINs they generate, we are proposing PTD requirements associated with the transfer of biointermediates between the biointermediate producer and the renewable fuel producer. The biointermediate producer would be required to transfer to the renewable fuel producer a PTD along with each
Additionally, to the extent that any portion of the biointermediate is not derived from renewable biomass, biointermediate producers would be required to identify the feedstock energies of the renewable and non-renewable biomass used to produce the biointermediate and the proportions of the biointermediate that could and could not be used to make renewable fuel for which RINs could be generated. If applicable, biointermediate producers would also need to convey information regarding the proportion of the biointermediate that is cellulosic material and non-cellulosic material. This breakdown would need to be transferred to the renewable fuel producer so they could properly calculate the RINs to be produced from fuel made with the biointermediate. Biointermediate producers would also need to certify to the renewable fuel producer the process used to produce the biointermediate feedstock. We seek comment on whether any additional information should be conveyed from the biointermediate producer to the renewable fuel producer through PTDs.
It should be noted that it would still be the responsibility of the renewable fuel producer to ensure that any feedstocks used to make renewable fuel, including biointermediates, meet the definition of renewable biomass, and that all processes used by the biointermediate producer in conjunction with the processes used by the renewable fuel producer fall under an EPA-approved pathway to produce renewable fuel. Thus, as discussed further in the next section, both the renewable fuel producer and the biointermediate producer may be held liable when RINs are generated for fuel that was not derived from renewable biomass, or where the biointermediate producer used processes that were inconsistent with the pathway utilized by the renewable fuel producer as the basis for RIN generation.
We are proposing to amend the regulations to add a new prohibited activity for the production of a biointermediate from a feedstock or through a process that is not described in the producer's registration information. We are also proposing to modify the prohibited acts regulations to prohibit the use of a biointermediate by a renewable fuel producer that is not described in the producer's registration information. Renewable fuel producers are ultimately responsible for ensuring that any biointermediate is used in compliance with the regulations, similar to how they are currently responsible for using appropriate feedstocks and processes to produce renewable fuels and generate RINs. As noted above, the description of feedstocks and processes in registration materials accepted by the EPA does not represent a determination by the EPA that such feedstocks and processes are consistent with the RFS regulations; the responsibility of ensuring that they do rests on a continuing basis with the renewable fuel producer as well as any biointermediate producer.
In order to fulfill the statutory mandate that renewable fuel is produced from renewable biomass, the renewable fuel producer must be able to demonstrate that the feedstocks they are using are, or are derived from, renewable biomass and are consistent with the feedstocks permitted under the renewable fuel production pathway utilized. When a biointermediate is being used to produce renewable fuel, the renewable fuel producer may not have direct access to the information needed to make these demonstrations. Therefore we are proposing that the biointermediate producer would be required to make these demonstrations both to the EPA and to the renewable fuel producer. To ensure appropriate levels of oversight by renewable fuel producers, we do not believe that the renewable fuel producer should be held harmless in the event that the biointermediate is determined to not be derived from renewable biomass or is determined to be unauthorized under the pathway utilized by the renewable fuel producer. Therefore we are proposing that either or both the biointermediate producer and the renewable fuel producer would potentially be liable for violations involving the improper production or characterization of a biointermediate used to produce renewable fuel for which RINs were generated. This would be true both where any errors could be characterized as having been made in good faith, and in situations involving deliberate fraud.
This approach has been used extensively in other EPA fuels programs (
We seek comment on whether the proposed approach to liability in instances where biointermediates are used is appropriate and whether the final regulations should include any additional prohibited activities or liability-related provisions.
We are proposing that biointermediate producers undergo annual attest engagements similar to current annual attest engagement requirements for renewable fuel producers. The attest engagement for biointermediate producers would consist of an outside certified public accountant or certified independent auditor following agreed upon procedures to determine whether the underlying records for the biointermediate, the reported items to the EPA, and copies of PTDs to the renewable fuel producer agree. The auditor would issue a report to the EPA as to their findings. We are also proposing a slight modification to the attest engagement for renewable fuel producers to ensure that attest auditors verify records related to the use of a biointermediate.
In 2014, the EPA finalized requirements for optional QAPs to help ensure that RINs are valid.
More significantly, we are proposing that in order for a renewable fuel producer to generate a Q-RIN, both the biointermediate producer and the renewable fuel producer must have in place an EPA-approved pathway-specific QAP. We believe that this is necessary to provide the level of assurance that is expected from the RFS QAP. If we allowed the producer to generate Q-RINs without the biointermediate producer's information being verified, it could undermine the level of compliance assurance provided by Q-RINs. Additionally, since the focus of the QAP system is the validity of RINs and both the biointermediate producer and the renewable fuel producer must follow approved pathway processes for RINs to be valid, it would not be appropriate to allow the generation of Q-RINs without a QAP for the biointermediate producer. We seek comment on whether this approach is appropriate and whether there are any additional QAP requirements that we should impose upon biointermediate producers or renewable fuel producers using biointermediates to maintain the high level of confidence associated with Q-RIN generation.
As discussed more thoroughly below, in the interest of accelerating the implementation of the proposed expanded program allowing use of biointermediates, we are proposing that in the interim between the effective date of the final rule and January 1, 2018, biointermediate producers and renewable fuel producers that wish to produce renewable fuel using biointermediate feedstock must have a pathway-specific QAP in place. We believe this is necessary because the tracking of biointermediates in EMTS and the association
We are proposing that foreign biointermediate producers have similar requirements as foreign renewable fuel producers as described in 40 CFR 80.1466. In general, foreign biointermediate producers would be required to comply with requirements related to inspection and audit, bonding, agent appointment for service of process, and the application of U.S. substantive and procedural laws to any civil or criminal enforcement action. These requirements would allow the EPA to monitor the producers and carry out enforcement actions should a violation occur outside the U.S.
We are also proposing that foreign biointermediate producers transfer their biointermediate only to domestic and foreign RIN-generating renewable fuel producers. This means that foreign biointermediate producers would not be allowed to transfer their biointermediate to non-RIN-generating foreign producers. This proposed limitation serves two purposes. First, RIN-generating renewable fuel producers are required to provide in EMTS the type and volume of the biointermediate used and the registration number of the biointermediate production facility. The existence of foreign biointermediate producer's information in EMTS allows the EPA to oversee all parties in the chain of RIN generation. Secondly, RIN-generating renewable fuel producers have the option to utilize the voluntary RFS QAP. The program helps ensure that RINs are properly generated through audits of renewable fuel production conducted by independent third-party auditors, and makes the RFS program more efficient for buyers of RINs. Foreign biointermediate producers would be subject to the same recordkeeping, reporting, registration, and PTD requirements as domestic biointermediate producers. We seek comment on the proposed foreign biointermediate producer requirements.
As mentioned above, some of the proposed requirements for biointermediates involve significant development of EMTS for the tracking of biointermediates and RINs generated for renewable fuel made from biointermediates. In addition, significant changes to the CDX registration system are needed to track the complex network of associations among biointermediate producers, renewable fuel producers, and, where relevant, independent third-party auditors. These changes are necessary to aid in implementing and enforcing the proposed biointermediate requirements. Additionally, by bringing biointermediates and biointermediate producers into EMTS and CDX, RFS regulated parties will be able to take full advantage of the tracking and transactional functions of the systems instead of having to track everything outside of the system.
On the other hand, the EPA does not want to delay the introduction of new renewable fuels that may help further the goals of the RFS program to significantly increase the production and use of renewable fuel as a substitute for fossil-based transportation fuel. We considered proposing a more manual tracking system, but given the significant investments already made to develop EMTS and the registration system, plus the benefits to the RFS regulated community of allowing biointermediates to be tracked with the full capabilities of EMTS and CDX, we believe it makes sense to require the tracking of biointermediate producers and biointermediates within the registration system and EMTS. Given the time needed to modify EMTS and CDX, we are proposing an interim
It should be noted that most of the proposed biointermediate requirements would go into effect at the start of the program and remain in place after the interim implementation period, including: Registration of biointermediate facilities, engineering review as part of registration, periodic reporting requirements outside of EMTS,
The main difference between the interim implementation program and the fully implemented program is that for the interim program biointermediate producers and renewable fuel producers using biointermediates must have EPA-approved pathway-specific QAPs. After the interim implementation period, we propose that parties could continue to voluntarily participate in the RFS QAP. Although the RFS QAP is otherwise a strictly voluntary program, we believe it is appropriate to require the participation of biointermediate producers and renewable fuel producers during the interim implementation period for two reasons. First, we want to reduce the opportunity for parties to generate invalid RINs. By allowing additional intermediate parties to collect and process feedstocks, the complexity of the relationship between feedstock providers and renewable fuel producers can be difficult to untangle and may provide opportunity for some parties to generate invalid RINs. Since RINs generated for renewable fuel produced from biointermediates would not be fully tracked in EMTS during the interim implementation period, requiring third-party verification of the production of biointermediates would provide both the EPA and the RFS regulated parties an additional increment of assurance that biointermediates are properly produced.
Second, requiring QAPs for biointermediate producers and renewable fuel producers during the interim implementation period is appropriate since this situation differs from the normal renewable fuel production situation. The use of a biointermediate as a feedstock by a renewable fuel producer is voluntary (
We recognize that this required QAP provision may temporarily place an additional burden on biointermediate producers and renewable fuel producers using biointermediates. However, we note that several companies that expressed interest to the EPA in producing or using biointermediates have mentioned the participation in the RFS QAP as a way to provide assurance that RINs are properly generated. We specifically seek comment on whether this interim implementation approach is appropriate, and whether any of the interim requirements (such as the mandatory use of a QAP) should be continued after the expiration of the interim period. We also seek comment on whether during the interim period there are any other measures that could be employed to provide the same type of assurance of RIN validity as the RFS QAP provides. In addition, should the EPA decide to not require the use of a QAP for all biointermediate producers and renewable fuel producers using biointermediates after the expiration of the interim period, we also seek comment on whether there are any specific situations in which the use of a QAP should continue to be mandatory, especially where the potential for fraud to occur may be more likely (
This section of the preamble discusses the EPA's proposed approach for EFF. An overview of the current regulatory provisions that apply to EFF is provided in section IV.A and an overview of the key proposed requirements that would apply to producers of EFF is provided in section IV.B. The proposed standards that would apply to EFF, EFF blendstocks, and EFF additives are discussed in section IV.C. The three different certification options for producers of EFF are discussed in section IV.D and the requirements for producers of E15 at blender pumps is discussed in section IV.E. The proposed compliance provisions that would apply to producers of EFF, including the registration, recordkeeping, reporting, PTD, sampling and testing, attest engagements, compliance dates, and EFF quality survey program, are discussed in section IV.F. An alternative approach that would formalize the current approved practices for producing EFF is discussed in section IV.G. A discussion of the EPA's statutory authority for these proposed requirements is provided in section IV.H.
FFVs are designed to operate on E0, E85, or any level of ethanol in between, and, in order to maintain emission performance, these vehicles need the fuel to meet certain quality specifications. Our various standards for gasoline apply to any fuel sold for use in motor vehicles, which is commonly or commercially known or sold as “gasoline.”
Gasoline-ethanol blends greater than 15 volume percent ethanol and less than 51 volume percent ethanol are relatively new to the marketplace. Fuels composed of at least 50 volume percent clear gasoline are included in the gasoline family under the F&FA program.
The EPA has two sets of gasoline quality requirements: One set applies to conventional gasoline (CG) areas and the other to reformulated gasoline (RFG) areas. The RFG requirements apply in areas with the greatest air quality need and are based on compliance with an emissions model that uses a number of gasoline properties to evaluate emissions control performance.
Under existing EPA regulations, a gasoline refiner must certify that the gasoline it produces meets the required emission performance standards by testing each batch.
E16-50 gasoline blends are currently produced for use in FFVs using blender pumps at fuel retailer facilities. The typical current practice is that a blender pump mixes gasoline (E0 or E10) and E85 parent blends at different ratios to produce various E16-50 blends. Such E16-50 blender pumps are a recent development.
Similarly, E15 is also primarily produced at blender pumps. Fuel retailers that make E15 at blender pumps using E85 as a parent blend are currently subject to all of the requirements that apply to refiners producing gasoline from crude oil, including registration, reporting, and per-batch testing. This is due to the fact that such blender pump operators are mixing non-gasoline (E85) with gasoline (E0 or E10) to produce a new finished gasoline.
The only current fuel quality requirement that applies to E85 is that it must be substantially similar (sub-sim) to the fuel used for FFV certification testing. To assure compliance with the sub-sim requirement, the EPA has required that E85 blenders can use only certified gasoline, BOBs, and DFE as E85 blendstocks, consistent with practices used in producing such blends for vehicle certification. Historically, this has not been an issue, as these were the
The proposed standards for EFF in this proposal will address the public health and welfare effects of EFF and its impact on emissions control devices on FFVs and FFV engines while providing new flexibility. The proposed standards are patterned on the EPA's Federal gasoline quality regulations and are designed to provide an equivalent level of emissions control performance when EFF is used in FFVs compared to the use of gasoline in conventional gasoline vehicles. As discussed above, the current regulations, as they relate to the production of E10, E15, and E16-50 at retail blender pumps include blender pump operators as subject to the requirements applicable to a gasoline refiner. These requirements include: Compliance with the health effects testing for the blends produced under the F&FA program; per-batch testing to demonstrate compliance with the sulfur, benzene, and RVP standards for gasoline; and registration, reporting, and recordkeeping requirements associated with demonstrating compliance.
In the Tier 3 proposal, we requested comment on several approaches for specifying standards that apply to E16-50 blends.
A number of comments on the Tier 3 proposal were in support of the EPA setting new standards for all EFF used in FFVs that would provide an equivalent level of protection to gasoline used in conventional gasoline vehicles and allow E16-50 to be made at blender pumps. However, the American Petroleum Institute (API) and the American Fuel and Petrochemical Manufacturers (AFPM) stated that the EPA should continue to treat E16-50 as gasoline to ensure an appropriate level of protection regarding the environmental quality of these blends.
In this action, we are proposing to adopt provisions to control the quality of all EFF blends, including E16-50. This proposal would make minor amendments to the regulations so that gasoline-ethanol blends of E50 and below that may not be used in conventional gasoline vehicles (currently E16-50)
We are also proposing fuel quality requirements for all EFF that would provide an equivalent level of emissions control when used in FFVs compared to the use of gasoline in conventional gasoline vehicles. As discussed in section IV.C of this preamble, the proposed sulfur and benzene standards and elemental composition requirements for EFF directly parallel those for gasoline since levels of these fuel parameters have the same impact on the emissions performance for FFV and conventional gasoline vehicles. The proposed RVP requirements for EFF recognize the greater capability of the evaporative emissions control equipment on FFVs compared to conventional gasoline vehicles. As a result of more stringent vehicle certification testing requirements, FFVs can deliver the same level of evaporative emissions control as conventional gasoline vehicles when operated on a fuel that is 1 psi higher than gasoline. We are proposing RVP standards for EFF produced upstream of blender pumps that parallel those for gasoline without the 1 psi waiver for E10 that applies in certain areas. When blended at retail, however, the RVP of the EFF would be expected to rise. The proposed RVP standards for EFF produced upstream of retail and existing RVP standards for gasoline would ensure that EFF produced at blender pumps using EFF and gasoline is expected to be less than 1 psi higher. We believe that the proposed standards for the EFF and gasoline parent blends used at blender pumps would ensure an equivalent level of evaporative emissions control for FFVs operated on EFF to that for conventional gasoline vehicles operated on gasoline (without the 1 psi waiver for E10) without necessitating the implementation of specific RVP standards for EFF produced at blender pumps.
The proposed compliance provisions contain two primary elements: (1) Recordkeeping and reporting; and (2) In-use verification through a third-party survey.
Since the EPA has not yet designated fuels other than gasoline and highway diesel fuel as motor vehicle fuel, fuels such as E85 (E51-83) are not yet subject to the EPA's F&FA regulations. By regulating all E16-83 ethanol blends together in a similar fashion and clarifying that E16-50 blends are not required to meet the requirements for gasoline under this proposal, we are resolving the ambiguity of E16-50 blends with respect to their treatment under both our F&FA program and in-use fuel quality regulations. We are exempting E16-50 blends that are used in FFVs from the designation for gasoline and we are not designating EFF blends (E16-83) as motor vehicle fuels under the F&FA program in this proposal.
The only current EPA fuel quality requirement for E85 is that it must be substantially similar (sub-sim) to vehicle certification fuel.
A number of stakeholders have requested that the EPA promulgate regulations to allow the use of natural gasoline as a blendstock to produce EFF due to its lower cost compared to gasoline. Natural gasoline is an inexpensive and increasingly plentiful byproduct of the ongoing expansion in domestic natural gas and crude oil production, and its use to make EFF would decrease EFF production costs. If this savings were passed along to consumers, it may help increase demand for EFF. Due to the relative high volatility of natural gasoline and the low volatility of ethanol, the use of natural gasoline to make E85 could also facilitate the manufacture of E85 in the upper end of its allowable range in ethanol content (
The current industry consensus-based controls on the quality of natural gasoline for use as an EFF blendstock
This proposal includes standards and compliance provisions that would allow the use of natural gasoline as a blendstock to produce EFF while providing an equivalent level of environmental performance to that for gasoline. Under this proposal, there would be two classes of natural gasoline that could be used to produce EFF: Certified natural gasoline EFF blendstock and uncertified natural gasoline EFF blendstock. Certified natural gasoline EFF blendstock would be certified by its producer as being compliant with standards for sulfur, benzene, and CHONS.
The proposed requirements are designed to assure that EFF produced with natural gasoline will meet the sub-sim requirements, protect emissions control systems on FFVs, and assure that FFVs that use EFF achieve the same or better emissions control performance as conventional gasoline vehicles. Alternatively, we are requesting
This proposal includes three options that EFF producers could use to demonstrate compliance with the proposed standards, as discussed in the following sections. The EFF full-refiner and EFF bulk blender-refiner certification options are intended for EFF producers upstream of retail or wholesale purchaser consumer (WPC) facilities (
This proposal would provide substantial additional flexibility for EFF producers that accommodate current market realities while ensuring that EFF used in FFVs is of sufficient quality to control pollution. The regulatory burden for the EFF producers who choose to take advantage of these flexibilities would be modest in comparison to the economic benefit realized by taking advantage of the flexibility, and largely consistent with current industry practices.
Under the first option for producing EFF (the “EFF full-refiner option”), uncertified natural gasoline EFF blendstock could be used to produce EFF provided that each batch is sampled and tested to demonstrate compliance with sulfur, benzene, and RVP standards similar to the requirements for a gasoline refiner. EFF full-refiners could also use certified gasoline, BOBs, certified natural gasoline EFF blendstock, DFE, and undenatured ethanol as EFF blendstocks.
Under the EFF full-refiner option, uncertified natural gasoline EFF blendstock of relatively higher sulfur and benzene content compared to certified natural gasoline EFF blendstock could be used to produce EFF as long as the potential impact on the sulfur and benzene levels in the finished EFF was mitigated by the use of lower sulfur/benzene DFE or undenatured ethanol. Ethanol producers have stated that allowing for such “ethanol dilution” would be important to broaden the potential pool of natural gasoline that could be used as EFF blendstock. Similar to the requirements for gasoline refiners, we are proposing that EFF full-refiners would be subject to a 0.62 volume percent annual average benzene standard, a 10 ppm annual average sulfur standard, an 80 ppm refinery gate per-gallon sulfur cap for the EFF they produce, and that the EFF they produce must be comprised solely of CHONS. Similar to the sulfur and benzene standards for gasoline refiners, compliance with the average sulfur and benzene standards for EFF produced or imported under the full-refiner option would be evaluated annually on an EFF refinery-by-refinery basis. However, we are not proposing to include EFF sulfur or benzene credit banking and trading (BT) provisions because we do not believe that such provisions are needed to mitigate the burden of compliance as was the case under the EPA's gasoline sulfur and benzene programs.
We are proposing that EFF produced by EFF full-refiners and EFF bulk blender-refiners and EFF sold at retail without further blending at a blender pump would be subject to a 9.0 psi RVP standard in CG areas where gasoline is subject to a 9.0 psi RVP standard, a 7.8 psi RVP standard in conventional gasoline areas where gasoline is subject to a 7.8 psi RVP standard, and a 7.0 psi RVP standard in reformulated gasoline (RFG) areas.
We expect that producers of EFF would only take on the additional compliance burden under the EFF full-refiner option to the extent that the proposed flexibility to use uncertified natural gasoline EFF blendstock would be economically advantageous. Producers that do not wish to take on the additional burden could use the streamlined compliance provisions under the EFF bulk blender-refiner option. We anticipate that some ethanol producers and perhaps some crude oil refineries may use the EFF full-refiner option.
Ethanol producers have stated that the proposed per-batch testing requirement is not consistent with the current practice of producing E85 by in-line blending as the fuel is dispensed into a tank truck for delivery downstream. Therefore, we are also requesting comment on alternatives to in-tank testing of each batch of finished EFF to streamline the compliance demonstration process. To demonstrate that EFF made with natural gasoline contains no non-CHONS elements, EFF full-refiners would be required to maintain records to document that the natural gasoline was sourced from a
The EFF full-refiner option would provide parties with the most blending flexibility, in exchange for taking on the added testing burden to demonstrate compliance. We anticipate that the majority of EFF would continue to be made by bulk blenders at petroleum terminals and ethanol plants where the per-batch testing requirement under the full-refiner option may not be practicable. Therefore, this proposal contains a second option for streamlined production of EFF (the “EFF bulk blender-refiner option”) for producers that only use blend components that have been certified upstream as meeting the applicable sulfur, benzene, and CHONS requirements. The standards and compliance demonstration requirements under this option are similar to those that apply to oxygenate blenders under the EPA's gasoline quality requirements.
We are also proposing that EFF bulk blender-refiners would be subject to the same RVP specifications proposed for EFF full-refiners. If EFF bulk blender-refiners limited the blendstocks they use to DFE and certified gasoline or BOBs that do not take advantage of the 1 psi waiver for E10, the EFF RVP blending characteristics would ensure compliance with the proposed RVP specifications for EFF. Therefore, we are proposing that EFF bulk blender-refiners that use only DFE and certified gasoline or BOBs that do not take advantage of the 1 psi RVP waiver for E10 could demonstrate compliance with the proposed RVP requirements for EFF simply by keeping records of the blendstocks they used and participating in the proposed EFF quality survey. Thus, such EFF bulk blender-refiners would not be required to conduct RVP testing on the EFF they produce.
The relatively higher volatility of certified gasoline or BOBs that take advantage of the 1 psi waiver for E10, and/or certified natural gasoline EFF blendstock means that EFF blends made using these blendstocks could potentially result in the finished EFF exceeding the proposed RVP specifications. Therefore, when EFF bulk blender-refiners use certified gasoline or BOBs that take advantage of the 1 psi waiver for E10, and/or certified natural gasoline EFF blendstock, there would be additional requirements to demonstrate compliance with the proposed RVP standards for EFF. EFF bulk blender-refiners that use these blendstocks could demonstrate compliance with the proposed RVP requirements through per-batch testing. However, since RVP testing of the small tank truck-sized batches of EFF that we expect EFF bulk blender-refiners would produce may be impractical, we are proposing that an RVP compliance tool could be used in lieu of per-batch testing to demonstrate compliance with the proposed RVP requirements by EFF bulk blender-refiners that use gasoline or BOBs that take advantage of the 1 psi waiver and/or certified natural gasoline EFF blendstock to produce EFF.
We are also proposing registration, recordkeeping, reporting, and PTD language requirements for EFF bulk blender-refiners. To ensure compliance, the producers of certified natural gasoline used by EFF bulk blender-refiners would be required to demonstrate that their product is compliant with EPA fuel quality requirements. EFF bulk blender-refiners would rely on the PTDs from the producers of the blendstocks they use to produce EFF to demonstrate compliance with the proposed sulfur, benzene, and CHONS requirements, rather than per-batch testing. We are proposing new registration, reporting, sampling, testing, and PTD requirements for producers of certified natural gasoline EFF blendstock to demonstrate that their product meets the following proposed standards: 10 ppm per-gallon sulfur cap, 0.62 volume percent benzene cap, 275 °F T90 distillation cap, 375 °F final boiling point cap, and 15 psi RVP cap. These sulfur and benzene standards for certified natural gasoline EFF blendstock are necessary to ensure that finished EFF has comparable levels of these fuel parameters to the levels present in gasoline when the potential dilution of these fuel parameters by ethanol cannot be evaluated as under the EFF full-refiner option. The T90 and final boiling point specifications would ensure that an uncharacteristic amount of higher boiling fraction hydrocarbons are not present. The RVP of EFF made with certified natural gasoline EFF blendstock would be controlled by the maximum RVP specifications for EFF discussed above. The proposed 15 psi RVP cap for certified natural gasoline EFF blendstock would help to ensure that an inappropriately high concentration of higher boiling compounds that are not typically native to natural gasoline are not present in significant quantities.
It is possible that a significant volume of natural gasoline that meets the proposed specifications for certified natural gasoline EFF blendstock without further processing could be segregated from the broader natural gasoline pool. Although there would be additional costs in segregating such naturally “sweet” natural gasoline from the general natural gasoline pool for use as certified natural gasoline EFF blendstock, such segregation costs would likely be lower than the additional processing costs to reduce the sulfur and benzene content of natural gasoline from the general natural gasoline pool to meet the proposed specifications. Therefore, segregation of such naturally sweet natural gasoline may be the initial means used to produce compliant certified natural gasoline EFF blendstock. Gasoline refiners would also find natural gasoline meeting the proposed standards for certified natural gasoline EFF blendstock a desirable gasoline blendstock.
The use of certified natural gasoline EFF blendstock to produce EFF would be voluntary. We expect that producers of certified natural gasoline and EFF bulk blender-refiners would only take on the additional costs to the extent that the proposed flexibility to use certified natural gasoline EFF blendstock to produce EFF would be economically advantageous. However, we expect that the cost savings from the use of certified natural gasoline EFF blendstock meeting the proposed standards compared to the use of gasoline or BOBs would far outweigh the costs of providing natural gasoline that meets the proposed specifications. EFF bulk blender-refiners that do not wish to take advantage of the proposed flexibility to use certified natural gasoline EFF blendstock could continue to blend EFF using gasoline, BOBs, and DFE as current E85 blenders do.
Compliance with the existing per-batch testing requirements in a retail setting is impractical because each vehicle fill-up would be considered a batch. Therefore, this proposal also includes a third option for the streamlined production of EFF by EFF blender pump-refiners at fuel retail and WPC facilities. The proposed EFF blender pump-refiner option does not have a parallel under current EPA fuels regulations. Historically, gasoline retailers have not produced or blended fuel, but only received certified batches of gasoline of like ethanol content (
To ensure proper fuel quality without placing unworkable testing requirements on each batch produced by a blender pump, we are proposing to limit the parent blends that can be used at blender pumps to produce EFF blends to compliant gasoline (E0, E10 with or without the 1 psi waiver, and E15) and EFF that satisfies the proposed fuel quality requirements.
Consistent with the gasoline volatility program, EFF parent blends at blender pumps and EFF at dedicated EFF dispensers would be required to be compliant with the proposed RVP requirements annually from June 1 through September 15 of each year. Also consistent with the gasoline volatility program, we are proposing a May 1 through September 15 RVP compliance period for all upstream parties to aid in the seasonal transition to RVP compliant EFF at retail facilities. EFF blender pump-refiners and operators of dedicated EFF dispensers would primarily rely on PTDs and participation in the proposed EFF quality survey to demonstrate compliance with the proposed RVP requirements. However, such retailers would also need to manage their EFF fuel deliveries to ensure that wintertime EFF that is not subject to the proposed RVP requirements is turned over to summertime RVP-compliant EFF by the proposed June 1 compliance date.
We believe that the RVP requirements on the parent blends used at blender pumps would provide effective control of the RVP of EFF produced at blender pumps. This is because the certification testing requirements for FFVs result in FFVs being equipped with evaporative emissions control equipment that is sized to control emissions when a 10 psi fuel is used. Conventional gasoline vehicles have evaporative emissions control equipment that is sized to control emissions from a 9.0 psi fuel. The proposed parent blend requirements for blender pump-refiners would ensure that the RVP of EFF blends made at blender pumps is expected to be less than 10 psi. This is for the worst case situation in CG areas where a 9.0 psi gasoline standard and the 1 psi waiver for E10 applies. In other areas with lower gasoline volatility requirements the RVP of EFF made at blender pumps would be correspondingly lower. Therefore, we believe that setting an RVP standard for E16-50 produced at blender pumps would not be necessary to prevent an increase in evaporative emissions from FFVs.
Under the current regulations, fuel retailers that produce E10 or E15 at blender pumps would be subject to the gasoline refiner provisions that require per-batch sulfur, benzene, and RVP testing.
All parties in the EFF distribution chain downstream of EFF full-refiners and EFF bulk blender-refiners and upstream of EFF blender pump-refiners would be subject to the proposed sulfur, benzene, RVP, and CHONS
The goal of these proposed quality standards for EFF is to ensure that FFVs provide the same level of emissions control performance as conventional gasoline vehicles. Since FFVs are equipped with the same catalysts and emissions control systems to control emissions as are conventional gasoline vehicles, FFV catalyst efficiency and emission control performance is subject to the same deleterious effects from fuel sulfur and atypical (non-CHONS) elements. The potential for benzene emissions from FFVs also correlates to the benzene content of the fuel used just as for conventional gasoline vehicles. The maximum RVP of fuels used in FFVs also must not exceed the capacity of the vehicle evaporative emissions control system, as it could result in uncontrolled emissions of volatile organic compounds (VOCs).
Similar to the gasoline sulfur program, the proposed standards that would apply to various parties in the EFF production and distribution system, and the means to demonstrate compliance with these standards would vary depending on their ability to affect EFF quality. This proposal contains three options under which an EFF producer can certify that their product is compliant with the applicable standards: The full-refiner option, the bulk blender-refiner option, and the blender pump-refiner option.
Under the Tier 3 gasoline program, the EPA promulgated a 10 ppm annual average sulfur standard and 80 ppm refinery gate per-gallon sulfur cap for gasoline in order to allow gasoline refiners flexibility to accommodate brief excursions from the sulfur average standard during upsets in the operation of gasoline desulfurization units.
The 10 ppm annual average sulfur standard would apply to all parties throughout the EFF distribution system as well as to EFF full-refiners. However, parties other than the EFF full-refiner, such as bulk blenders, distributors, and retailers, would be deemed to be in compliance with the 10 ppm annual average sulfur standard if they maintain records to demonstrate they did not introduce uncertified blendstocks into the EFF they produce or distribute. The sulfur content of EFF produced by bulk blender-refiners and blender pump-refiners would be governed by the blending restrictions that accompany these certification options. All of the approved blend components would be subject to a 10 ppm annual average sulfur standard or a more protective 10 ppm per-gallon sulfur cap standard.
Consistent with the downstream gasoline sulfur standard under the current Tier 2 gasoline program and the Tier 3 gasoline program that will become effective January 1, 2017, we are proposing that EFF would be subject to a 95 ppm per-gallon sulfur cap standard downstream of EFF full-refiner facilities. This 95 ppm per-gallon sulfur cap would apply to EFF bulk blender-refiners, EFF blender pump-refiners and all other parties in the EFF distribution system downstream of EFF full-refiners. We believe that this would be sufficient to accommodate the use of gasoline that meets the 95 ppm per-gallon sulfur cap as an EFF blendstock by EFF bulk blender-refiners, and sulfur contamination from the use of downstream sulfur-containing EFF additives. An additional 15 ppm from the 80 ppm refinery gate sulfur cap was provided for gasoline downstream of the refinery gate under the Tier 3 gasoline program to allow for the most extreme cases where sulfur might be added to gasoline as a result of contamination during distribution or through the use of additives when sulfur is an essential functional component in the additive (
We believe that distributors of EFF should be able to limit sulfur contamination at least as effectively as distributors of gasoline because EFF cannot be distributed by pipeline, which is where there is the highest potential for sulfur contamination of gasoline. The one link in the EFF production chain where unique concerns may exist regarding limiting sulfur contamination is in the distribution of certified natural gasoline EFF blendstock. The procedures necessary to limit contamination to the level required under this proposal may not be familiar to distributors of natural gasoline since natural gasoline is typically subject to broader quality specifications than those proposed for use as an EFF blendstock. Hence, there may be an increased chance for sulfur contamination of certified natural gasoline EFF blendstock during distribution from other higher-sulfur natural gasoline in the distribution chain during the initial phase-in of the program. The proposed 10 ppm per-gallon sulfur cap on certified natural gasoline EFF blendstock would apply throughout the distribution chain, including at the EFF full-refinery or bulk blender-refinery that uses certified natural gasoline EFF blendstock to make EFF. Therefore, sulfur contamination during the distribution of certified natural gasoline EFF blendstock should not impact the sulfur content of EFF. We would work with the producers, distributors, and users of certified natural gasoline EFF blendstock to make them aware of their responsibility to limit contamination during distribution during the implementation of the final rule.
Gasoline additives exist that are suitable for use in EFF. To the extent that additives may be specifically designed for use in EFF, we believe that such additives would not require higher sulfur content as an essential functional component to a greater extent than that
The gasoline sulfur control program includes banking and trading (BT) provisions for sulfur credits across gasoline production facilities and companies. These BT provisions were included to address concerns that it would be difficult and costly for refiners to install the necessary desulfurization equipment to reduce the sulfur content of gasoline down to a 10 ppm annual average due to the high levels of sulfur naturally occurring in crude oil. In comparison, EFF producers could comply with the proposed sulfur specifications simply by using existing low sulfur DFE and gasoline as blendstocks as they do currently. Such EFF producers would have only minimal additional recordkeeping and PTD requirements as a result of this proposal.
API and AFPM commented on the Tier 3 proposal that BT provisions should be included for E16-50 producers and that the trading of credits generated under such provisions should be allowed to be used by gasoline refiners to demonstrate compliance with the gasoline sulfur standards. We do not believe that there is a need to allow any additional source of sulfur credits to enable compliance with the Tier 3 gasoline standards, and given the large volume difference, we believe allowing gasoline sulfur credits to be used for EFF compliance would circumvent reducing EFF sulfur levels to 10 ppm. Therefore, we are not proposing to allow any credit trading between EFF and gasoline.
We are proposing that EFF would be subject to the same 0.62 volume percent annual average benzene standard that applies to gasoline. The Tier 3 proposal requested comment on the potential that EFF might be able to satisfy more stringent benzene requirements due to a potential increased benzene dilution effect in higher ethanol content blends.
EFF full-refiners would be required to test each batch of EFF to demonstrate compliance with the proposed annual average benzene standard. The 0.62 volume percent annual average benzene standard would apply to all parties throughout the EFF distribution system as well as to EFF full-refiners. However, parties other than EFF full-refiners, such as bulk blenders, distributors, and retailers, would be deemed to be in compliance with the 0.62 volume percent annual average benzene standard if they maintain records to demonstrate that they did not introduce uncertified blendstocks into the EFF they produce or distribute. Similar to the discussion above regarding sulfur, we are proposing that the benzene content of EFF produced by bulk blender-refiners and blender pump-refiners would be governed by the blending restrictions that accompany these certification options. All of the approved blend components would be subject to a 0.62 volume percent annual average benzene standard or a more protective benzene per-gallon cap standard.
Similar to the proposed EFF sulfur standards, we are also not proposing a BT program for the EFF benzene standards. We believe that the same conditions that led the EPA to include provisions under the gasoline benzene program for BT of benzene credits are not present for EFF full-refiners and importers. We do not expect that EFF full-refiners and importers would need to install processing equipment to remove benzene from EFF to meet the proposed 0.62 volume percent annual average benzene standard as was the
Volatility is a measure of the propensity of a liquid to evaporate. RVP is a standard measure of fuel volatility at 100 °F. The amount of evaporative emissions from a gasoline blend is closely related to its volatility. The components of gasoline and EFF have different volatilities because of their unique chemical make-up. The RVP of a finished gasoline made solely from the various hydrocarbons in the gasoline boiling range is essentially proportional to the RVP and blend ratios of the individual hydrocarbon blend components. That is to say, the RVP of gasoline hydrocarbons blends linearly similar to gasoline sulfur and benzene content. This is not the case when ethanol is added to gasoline. The addition of ethanol to gasoline increases the volatility of the blend until a concentration of approximately 10 volume percent, after which increasing ethanol concentration slowly decreases blend volatility. For example, for ethanol blends made with a 9 psi RVP gasoline (E0), the RVP increases to approximately 10 psi at 10 volume percent ethanol (E10) then decreases gradually with increased ethanol concentration to 9 psi at 50 volume percent ethanol (E50), and continues to decrease at a more pronounced rate to 6 psi at 80 volume percent ethanol (E80).
As previously explained, FFVs are equipped with the same type of emissions control equipment to limit evaporative VOC emissions as are conventional gasoline vehicles. Controlling the volatility of EFF is important to limit the evaporative emissions from FFVs. Higher fuel volatility levels generates additional fuel vapor in a vehicle or engine fuel system that can cause “breakthrough” emissions from the evaporative emission control system of a vehicle or engine.
We believe that the maximum RVP requirements for gasoline are an appropriate benchmark to consider in determining what RVP standards to set for EFF. A 9.0 psi RVP maximum applies to gasoline in many CG areas, while a 7.8 psi RVP applies in certain southern CG areas where ambient temperatures are warmer, causing fuel volatility to be higher for a given RVP.
Although FFVs are equipped with the same type of evaporative emissions control equipment as conventional gasoline vehicles, differences in the evaporative emissions testing requirements results in the evaporative emissions control equipment on FFVs being more robust than that installed on conventional gasoline vehicles. The capacity of vehicle evaporative emissions control equipment is driven by the vehicle evaporative emissions certification testing requirements. Vehicle evaporative emissions certification testing includes testing to evaluate both diurnal and refueling evaporative emissions. A 9.0 psi test fuel is specified for both diurnal and refueling evaporative emissions certification testing for conventional gasoline vehicles. Hence, the evaporative emissions control systems of conventional gasoline vehicles are sized to reliably cope with a maximum 9.0 psi RVP in-use fuel without breakthrough evaporative emissions.
Historically, and at present, FFVs are certified for both diurnal and refueling evaporative emissions compliance on the highest volatility fuel typically encountered in-use during the May 1 through September 15 volatility control period (
At the same time, as noted above, the RVP standard for gasoline in some a reas is set below 9.0 psi (at 7.8 psi in certain CG areas or effectively 7.0 psi in RFG areas) to provide greater protection from excess emissions, either due to climatic considerations or ambient pollution concentrations.
The manufacture of EFF blends at blender pumps presents unique challenges with respect to ensuring volatility control since the RVP of such blends is often higher than that of either parent blend. For example, the RVP of EFF blends made at a blender pump using two parent blends (E10 and EFF), each less than 9 psi RVP, would be somewhat higher than 9 psi.
We conducted RVP modeling to evaluate what RVP standards for the EFF blends used as parent blends at blender pumps would provide adequate control of the RVP of EFF blends produced at blender pumps.
As discussed above, we believe that limiting the RVP of EFF produced at blender pumps to the target levels described above would provide a comparable level of evaporative emissions for FFVs operated on EFF compared to conventional gasoline vehicles operated on gasoline. The RVP modeling results indicate that the RVP of EFF blends made at blender pumps would exceed the target maximums by only as much as 0.2 psi using worst-case assumptions.
Therefore, we are proposing that the RVP requirements for EFF for full-refiners, importers, and bulk blender-refiners would generally track those of gasoline, with a maximum RVP of 9.0 or 7.8 psi for CG areas (depending on the applicable gasoline RVP standard), and an RVP maximum of 7.0 psi for RFG areas (which is comparable to the average RVP of RFG). We are soliciting comment on these standards. We also seek comment on setting a 9.0 RVP standard for EFF produced by full-refiners, importers, and bulk blender-refiners for use in all CG areas rather than imposing lower standards commensurate with the lower gasoline RVP standards that apply in certain areas.
We believe that the proposed parent blend requirements for EFF blender pump-refiners, including the proposed RVP standards for EFF produced by EFF full-refiners and bulk blender-refiners discussed above would provide sufficient control of the RVP of EFF made at blender pumps. Therefore, we do not believe that an RVP standard for EFF produced at blender pumps is needed at this time. We are also proposing an independent survey of the RVP of EFF at blender pumps.
Similar to the gasoline RVP requirements, we are proposing that the proposed EFF RVP standards would apply to EFF retailers and WPCs from June 1 through September 15 and to all other parties in the EFF production and distribution system from May 1 through September 15 of each year. Thus, a retailer or WPC would be liable for RVP violations if their EFF parent blends or EFF blends distributed from a dedicated dispenser exceeded these RVP limits from June 1 through September 15 and upstream parties would be liable for the RVP of the EFF they produce or distribute from May 1 through September 15. The EPA could evaluate compliance with these standards by sampling and testing the EFF parent blends from the underground storage tank. We seek comment on whether the EPA could evaluate compliance by setting the blender pump to dispense EFF only, flushing the pump, and collecting a sample from the blender pump dispenser.
We believe that E51-83 blends produced with the hydrocarbon blendstocks allowed under the current requirements for E51-83 (gasoline and BOBs) would necessarily meet the proposed maximum RVP requirements as a result of the volatility blending characteristics. In fact, at high ethanol concentrations, E85 is currently challenged to have sufficiently high RVP to meet the minimum ASTM volatility specification for proper vehicle cold start and driveability. Therefore, the proposed RVP requirements would not result in a further constraint to E51-83 RVP blending practices compared to the current situation. Rather, the proposed increased flexibility to use natural gasoline as an EFF blend component would likely allow the RVP of EFF to increase up to the evaporative control limits of FFVs. This should not only help E51-83 meet the minimum ASTM volatility specification at greater ethanol concentrations, but also reduce the cost of all EFF and potentially improve the exhaust emission performance of FFVs. Since the proposed EFF RVP standards parallel those for gasoline, this would
ASTM has set minimum volatility specifications on E51-83 for safety reasons and to ensure adequate startability and drivability, which are critical for exhaust emission performance.
Elements that can poison (deactivate) vehicle emission control catalysts such as anions or cations (
Emissions certification testing of FFVs is required using both the test fuel specified for conventional gasoline vehicles and a high ethanol content FFV test fuel (E83). Regulatory specifications for conventional gasoline emissions certification test fuel have long existed to ensure that atypical elements are not present. Regulatory specifications for the high-ethanol content FFV certification test fuel were finalized in the Tier 3 final rule and will become mandatory for model year (MY) 2017 FFVs.
Non-CHONS elements are typically removed during the processes used to produce gasoline compliant with EPA sulfur standards at crude oil refineries. Hence, the EPA has had good assurance that gasoline refiners are complying with the CHONS requirement despite the lack of a testing requirement or specific limit on the quantities of atypical elements that may be present in gasoline. The main potential source of atypical elements in gasoline is additives added to gasoline after the gasoline is produced at a crude oil refinery; however, such additives are also required to be CHONS.
E51-83 was also assured to be composed of only CHONS when gasoline and BOBs were the only hydrocarbon blendstocks used in its manufacture. E16-50 has been assured to be CHONS by the current provisions that apply the requirements applicable to gasoline to these blends and the fact that it is typically blended from E51-83 and E10. This proposal includes provisions to treat all E16-83 as EFF and to allow EFF full-refiners, importers, and EFF bulk blender-refiners to use natural gasoline to produce EFF. There is no existing CHONS requirement for natural gasoline used as an EFF blendstock. Therefore we are proposing that EFF would be required to be CHONS, and are proposing additional CHONS requirements on natural gasoline EFF blendstock. We believe that the proposed provisions for natural gasoline EFF blendstock and the existing provisions for the other EFF blendstocks would ensure that EFF would be CHONS.
Special provisions were provided under the gasoline sulfur program to accommodate additives that require sulfur in their functional components. These provisions allowed the continued use of such important additives while ensuring compliance with the 95 ppm downstream per-gallon sulfur cap for gasoline. We are proposing that additives used in EFF would be subject to the same sulfur requirements that apply to additives used in gasoline.
We believe that there would be no need for the use of additives in certified natural gasoline EFF blendstock from the point of its production to its use to produce EFF. Therefore, we are proposing to prohibit the addition of additives to certified natural gasoline EFF blendstock. We request comment on whether provisions including sulfur standards are needed to facilitate the use of additives in certified natural gasoline EFF blendstock. If we were to finalize provisions to allow the use of additives in certified natural gasoline EFF blendstock, the use of additives that contain non-CHONS elements such as metals would be prohibited unless the EPA were to determine that the use of such an additive would not cause or contribute to regulated emissions failures of FFVs, and granted a waiver to allow its use in EFF pursuant to the requirements of CAA section 211.
We also believe that there would be no need for the use of additives in uncertified natural gasoline EFF blendstock from the point of its production to its use to produce EFF. EFF full-refiners that use uncertified natural gasoline EFF blendstock are required to test each batch of finished EFF. Therefore the potential impact on the sulfur and benzene content from the possible addition of additives to uncertified natural gasoline EFF blendstock would be reflected in the per-batch EFF testing required of EFF full-refiners, and there would be no need for sulfur or other standards for such additives. The use of additives that contain non-CHONS elements such as metals in uncertified natural gasoline EFF blendstock would be prohibited unless the EPA were to determine that the use of such an additive would not cause or contribute to regulated emissions failures of FFVs, and granted a waiver to allow its use in EFF pursuant to the requirements of CAA section 211. We are proposing that EFF full-refiners would be required to secure a PTD from the uncertified natural gasoline EFF blendstock supplier that demonstrates that it contains no non-CHONS elements.
The current deposit control regulations require that the gasoline portion of E51-83 must contain a certified deposit control additive at a concentration at least as great as that used during gasoline deposit control additive certification testing (referred to as the lowest additive concentration or LAC).
We continue to believe that the current deposit control requirement for the gasoline portion of E51-83 is not providing a meaningful benefit to deposit control in these blends and may actually contribute to deposits. There is currently insufficient data regarding the potential effects of deposits on FFV emissions and what regulatory specifications may be appropriate for deposit control additives used in EFF. Likewise there are no test procedures that might be used for regulatory purposes. Therefore, we are proposing to amend the regulations to remove the requirement that the gasoline portion of E51-83 must contain a certified deposit control additive.
There are similar concerns regarding using deposit control additives certified for gasoline use in E16-50. Consequently we are also proposing to defer setting deposit control requirements for E16-50. We appreciate the concerns expressed in the comments on the Tier 3 proposal that all spark ignition fuels, including EFF, should be required to provide a minimum level of deposit control. We may consider adopting deposit control requirements for EFF in a later action should appropriate deposit additives and test procedures be developed for use with EFF and data become available to establish that there is sufficient environmental need. In the meantime, we believe that the resolution of this issue is best left to the marketplace.
EPA-compliant gasoline, BOBs, and DFE can be used to produce E85 under the current regulatory requirements. There are already regulations in place under the EPA's gasoline program regarding the sulfur, benzene, and presence of atypical elements in such blendstocks that assure they are of sufficient quality for use in vehicle fuels (including all EFF). This proposal would create a new classification of certified natural gasoline EFF blendstock that could also be used by EFF bulk blender-refiners. This proposal would also create a new classification of uncertified natural gasoline EFF blendstock that could be used by EFF full-refiners. Therefore, new fuel quality requirements are needed for such natural gasoline EFF blendstocks. We are proposing that hydrocarbons that are imported for use as an EFF blendstock must be sourced from a foreign refiner that is registered with the EPA. We believe that this requirement is
To ensure that the use of certified natural gasoline as an EFF blendstock by EFF full-refiners and bulk blender-refiners does not result in increased FFV emissions, we are proposing that producers of certified natural gasoline EFF blendstock must demonstrate compliance with proposed quality requirements regarding sulfur and benzene content. We are also proposing that certified natural gasoline EFF blendstock be composed solely of CHONS.
The natural gasoline that is typically used to denature ethanol is likely unsuitably high in sulfur and benzene content to ensure adequate FFV emission control performance.
However, if ethanol denaturant is used as a blendstock in EFF, the concentration of such denaturant relative to the undenatured ethanol used would be substantially higher than in DFE, resulting in insufficient dilution of the sulfur and benzene present in the denaturant. For example, if 30 percent denaturant at 330 ppm sulfur was used with 70 percent undenatured ethanol to make E70, the resulting sulfur content of the finished E70 would consistently be close to 100 ppm. Such consistently high sulfur levels in EFF would result in significant FFV emissions control catalyst performance degradation and a substantial increase in FFV emissions.
Therefore, to ensure that the emissions control equipment of FFVs running on EFF are not impaired and that FFVs have the same emissions performance as conventional gasoline vehicles running on gasoline, we are proposing that certified natural gasoline EFF blendstock would be required to meet a 10 ppm per-gallon sulfur cap and a 0.62 volume percent per-gallon benzene cap. These proposed standards would be consistent with the average standards applicable for gasoline and would ensure that the sulfur and benzene content of EFF made by bulk blender-refiners is equivalent to the levels found in gasoline without the need to impose a per-batch testing requirement.
We are proposing that certified natural gasoline EFF blendstock would be required to be composed solely of CHONS similar to the requirement for gasoline producers. To ensure that certified natural gasoline EFF blendstock is CHONS, we are proposing that it would be required to be sourced from either a natural gas processing facility or a crude oil refinery. We are proposing that a natural gas processing plant means a facility designed to “clean” raw natural gas by separating impurities and various non-methane hydrocarbons and fluids to produce what is known as “pipeline quality” dry natural gas. A gas processing plant is used to recover natural gas liquids including natural gasoline and to remove other substances such as sulfur and benzene from natural gasoline EFF blendstock as needed.
To prevent an inappropriately high concentration of high boiling point hydrocarbons in natural gasoline, we are proposing 275 °F T90 distillation and 375 °F final boiling point specifications consistent with a commonly observed
We are proposing that certified natural gasoline EFF blendstock would be subject to a 15 psi RVP maximum specification. This would provide additional assurance that an abnormally high fraction of higher boiling compounds are not present that could lead to unexpected vehicle performance issues that could adversely impact FFV emissions. We believe that this is consistent with current industry practice that limits natural gasoline RVP to below atmospheric pressure (14.7 psi) to avoid the need for more costly storage vessels.
We are also proposing that refiners and importers of certified natural gasoline EFF blendstock would be required to register with the EPA, submit batch reports annually, and issue PTDs indicating that their product is suitable for use by EFF bulk blender-refiners. We are proposing that the PTD also include the RVP of the natural gasoline to facilitate use of the proposed RVP tool to demonstrate compliance by EFF bulk blender-refiners with the proposed maximum RVP specification.
The proposed RVP requirements for EFF would typically limit the amount of natural gasoline that could be used to make EFF from May 1 through September 15 for parties upstream of retail and WPC facilities to about 30 volume percent.
The industry consensus ASTM standard for E51-83 allows the use of natural gasoline as a blendstock.
We believe that these proposed standards are necessary to ensure that the proposed flexibility to allow natural gasoline use as an EFF blendstock would not result in increased FFV emissions. ASTM recently published a standard that for the first time put in place a level of quality control for natural gasoline used as an E51-83 blendstock.
We believe the economic incentive provided by this new flexibility would be sufficient for natural gasoline producers to take the necessary steps to provide certified natural gasoline EFF blendstock to EFF full-refiners and bulk blender-refiners. For example, E70 could be produced with approximately 30 volume percent natural gasoline while meeting the proposed 9 psi maximum RVP standard in CG areas.
EFF full-refiners could use uncertified natural gasoline EFF blendstock provided that they demonstrate that each batch: (1) Was sourced from a natural gas processing plant or crude oil refinery; (2) Meets 275 °F T90 distillation and 375 °F final boiling point specifications; and (3) Meets a maximum 15 psi RVP specification. These requirements parallel those proposed above for certified natural gasoline EFF blendstock to ensure that non-CHONS elements are not present and that an undue fraction of heavy or light boiling fractions are not present. EFF full-refiners could test each batch of uncertified natural gasoline EFF blendstock to demonstrate compliance with the proposed T90, final boiling point, and maximum RVP specifications. EFF full-refiners would also need to obtain documentation from their suppliers that demonstrates that uncertified natural gasoline EFF blendstock was sourced from a processing unit such as a distillation tower and/or desulfurization unit at natural gas processing plant or crude oil refinery. Such documentation would need to establish that the uncertified natural gasoline had received some processing at a natural gas processing plant or crude oil refinery, such as in a distillation tower and/or desulfurization unit. We are not proposing sulfur or benzene specifications for uncertified natural gasoline EFF blendstock because EFF full-refiners would already be required to test each finished batch of EFF to demonstrate compliance with the proposed sulfur and benzene specifications for EFF.
We request comment on allowing butane and pentane that meets the requirements for downstream gasoline blending to be used as blendstocks by EFF full-refiners and bulk blender-refiners.
Ethanol producers have requested that the EPA consider a means to certify a grade of DFE that meets lower sulfur and benzene caps for use with a grade of certified natural gasoline EFF blendstock that meets higher sulfur and benzene standards than those proposed above. The respective sulfur and benzene standards for these grades would be set to provide equivalent sulfur and benzene levels in the finished EFF blends produced as would be achieved by using DFE that meets the existing requirements
The use of undenatured ethanol as an EFF blendstock rather than DFE might provide even more opportunity for dilution of the sulfur and benzene content of natural gasoline used as an EFF blendstock. Hence, there may also be the potential for yet another grade of certified natural gasoline EFF blendstock with somewhat higher sulfur and benzene specifications to be used at ethanol production plants in combination with undenatured ethanol to make EFF. Under such an approach, the sulfur and benzene content of the undenatured ethanol could be considered negligible provided that the producer maintains production quality control records to demonstrate that
Ethanol producers stated that including such additional grades of DFE and natural gasoline EFF blendstock would allow access to a larger volume of natural gasoline for blending into EFF. This approach would necessitate additional product segregation, PTD, reporting, and recordkeeping requirements to ensure that the different grades of certified natural gasoline were used under the appropriate circumstances. For example, all parties in the production and distribution system would need to segregate and keep records on the various grades of certified natural gasoline they handle and maintain PTD records. We request comment on this approach, including what standards would be appropriate for the additional grades of DFE and natural gasoline EFF blendstock discussed above, and the means of simplifying its implementation while ensuring enforceability.
The following paragraphs discuss several provisions and exemptions from the proposed EFF standards in special circumstances.
Due to national security considerations, some of the EPA's existing regulations allow the military to request and receive National Security Exemptions (NSEs) for vehicles, engines, and equipment from emissions regulations if the operational requirements for such vehicles, engines, or equipment warrant such an exemption. In our diesel fuel program and the Tier 2 and Tier 3 gasoline sulfur programs, we provide an exemption for fuel used in tactical military vehicles and nonroad engines and equipment with a NSE from the vehicle and engine emissions standards. Fuel used in these applications would also be exempt if it is used in tactical military vehicles, engines, or equipment that are not covered by an NSE but, for national security reasons (such as the need to be ready for immediate deployment overseas), need to be fueled on the same fuel as those with an NSE. We are proposing to extend this exemption to EFF as well.
Similar to existing EPA fuels programs, we are proposing to allow for requests for an exemption from the EFF standards for EFF used for research, development, and testing purposes (“R&D exemption”). We recognize that there may be legitimate research programs that require the use of EFF with benzene, sulfur, or RVP levels greater than those allowed under the proposed EFF requirements. Thus, we are proposing provisions for obtaining an exemption from the prohibition against persons producing, distributing, transporting, storing, selling, or dispensing EFF that does not meet the EFF standards, where such fuel is necessary to conduct a research, development, or testing program.
Parties seeking an R&D exemption would be required to submit an application for exemption to the EPA that describes the purpose and scope of the program, and the reasons why the noncompliant EFF is necessary. Upon presentation of the required information, an exemption could be granted at the discretion of the EPA, with the condition that the EPA could withdraw the exemption in the event the EPA determines the exemption is not justified. In addition, an exemption based on false or inaccurate information would be considered void
EFF produced for export, and that is actually exported for use in a foreign country, would be considered exempt from the fuel content standards and other requirements of the proposed EFF program. In order to exclude exported EFF, refiners would have to retain records to demonstrate that the EFF was exported. Such EFF would have to be designated by the EFF refiner for export, and the PTD would have to state that the EFF is for “export only;” otherwise, the EFF would be considered as intended for use in the U.S. and subject to the proposed EFF standards. EFF intended for export would be required to be segregated from all EFF intended for use in the U.S. Distributing or dispensing such fuel for domestic use would be illegal.
The current State of California requirements for EFF do not parallel those we are proposing for EFF.
We are proposing to exempt California EFF from the requirements in this proposal provided that California EFF is segregated from federally compliant EFF, and PTD and recordkeeping requirements are observed for California EFF. These proposed requirements are similar to those associated with the current exemption from federal sulfur standards for California diesel fuel that meets California diesel fuel standard. We believe that it is appropriate to exempt California EFF from the requirements in this proposal to allow California the latitude to regulate EFF in a manner that is consistent with the state's unique air quality needs and the requirements under the state's Low Carbon Fuel Standard (LCFS) program.
Additionally, in existing EPA fuels programs we have included exemptions for racing fuel and for fuel used in the U.S. territories of Guam, American Samoa, and the Northern Mariana Islands. We have included these same exemptions for the proposed EFF requirements and request comment on whether or not such exemptions would be needed for this program.
All producers or importers of EFF are considered EFF refiners, and thus responsible for demonstrating that the EFF blends they produce or import meet EPA quality requirements. This proposal contains three options under
Under the proposed EFF full-refiner option, refiners and importers of EFF blends could use certified and uncertified natural gasoline ethanol flex fuel blendstock, certified gasoline, BOBs, DFE, and undenatured ethanol as EFF blendstocks,
EFF full-refiners would be required to register each facility, provide annual reports on the EFF produced, issue compliant PTDs for each EFF batch, and maintain records to demonstrate compliance. As part of the proposed annual reporting requirement, EFF full-refiners would be required to certify that the EFF they produced or imported is compliant with the proposed CHONS requirement in addition to providing batch test data to demonstrate compliance with the other proposed quality requirements. EFF full-refiners would have complete responsibility to demonstrate compliance of the uncertified natural gasoline they use as an EFF blendstock with the proposed requirements. To support that the uncertified natural gasoline is CHONS, EFF full-refiners would be required to maintain records to demonstrate the uncertified natural gasoline blendstock used was sourced only from processing units at natural gas processing plants or crude oil refineries and that no non-CHONS additives were added.
We are proposing that EFF full-refiners would be the only party that could designate natural gasoline as uncertified natural gasoline EFF blendstock and that uncertified natural gasoline blendstock could not be transferred to another party. EFF full-refiners could use bills of lading and certificates of analysis from their natural gasoline supplier to help demonstrate compliance with the requirements for uncertified natural gasoline EFF blendstock. Therefore, we believe that there is no practical reason to allow an entity upstream of an EFF full-refinery to designate natural gasoline as uncertified natural gasoline EFF blendstock or for natural gasoline designated as uncertified natural gasoline EFF blendstock to be transferred to another party.
We are proposing that EFF batch certification testing would be conducted on a “certification tank” of EFF where individual samples are drawn from the top, middle, and bottom of the tank to ensure that the test results are representative, consistent with existing gasoline tank sampling requirements.
For EFF full-refiners that are also alcohol fuel plants under the Alcohol and Tobacco Tax and Trade Bureau (TTB) regulations, the addition of at least two volume percent uncertified natural gasoline blendstock would result in distilled spirits that are unfit for beverage use. As a result, unlike other EFF refiners, EFF full-refiners have the option to blend in uncertified natural gasoline blendstock to accomplish EFF blending and denaturing of ethanol in one step. As prescribed in 26 U.S.C. 5181, when the distilled spirits are produced under the statutory and regulatory provisions for fuel use and are being withdrawn exclusively for fuel use the fuel alcohol is withdrawn free of tax.
While we anticipate that most current E85 blenders would use the following EFF bulk blender-refiner option, ethanol producers have expressed interest in this EFF full-refiner option. We understand that the proposed EFF certification tank requirements are not well suited to the existing EFF production methods at ethanol production plants where the various component blendstocks are mixed at set ratios via in-line blending to produce EFF as it is pumped into tank trucks or rail cars for downstream delivery. Therefore, we are requesting comment on alternatives to the proposed certification tank approach to streamline compliance for ethanol producers that wish to take advantage of the EFF full-refiner option, which would still be able to be used to ensure compliance.
Under one such alternative, a “hand blend” option, a representative sample of EFF at a given blend ratio would be made up from representative samples of the individual EFF blendstocks. To create a representative sample of each
Much of the E51-83 is currently made at petroleum terminals and ethanol production facilities by mixing blendstocks in prescribed ratios via in-line blending as the fuel is delivered into tanker trucks for delivery to retail stations. We anticipate the vast majority of E51-83 will continue to be made by such bulk blenders at gasoline terminals and ethanol plants. The small batch size and timing constraints when E51-83 is made as the product is dispensed into a tank truck for delivery to retail and WPCs facilities would likely make the per-batch EFF sulfur and benzene testing requirements under the EFF full-refiner option impractical for EFF bulk blender-refiners. There is also no clear technical path to facilitate per-batch RVP testing under such circumstances since such testing could introduce unacceptable delay during tank trucks picking up EFF at product terminals. Therefore, we are proposing the EFF bulk blender-refiner certification option under which bulk blenders could avoid per-batch testing by using only previously certified blendstocks, where much of the compliance demonstration has been accomplished by the blendstock producer. The only blend components that such bulk blenders can currently use while being assured of compliance with the existing sub-sim requirement for E51-83 are gasoline, BOBs, and DFE. We are proposing to expand this list of blend components to allow for increased EFF production.
We are proposing that to be treated as an EFF bulk blender-refiner, bulk blenders would be limited to using the following blendstocks that had been certified by their producers as meeting EPA quality requirements to produce EFF: DFE, gasoline, BOBs, and certified natural gasoline EFF blendstock.
EFF bulk blender-refiners that continue to use only DFE and certified gasoline/BOBs that do not take advantage of the 1 psi waiver for E10 to make E51-83 would have only minimal additional regulatory burdens under this proposal associated with registration, annual reporting, recordkeeping, PTDs, and participation in the proposed EFF quality survey. EFF bulk blender-refiners that choose to take advantage of the proposed new blending flexibility to use natural gasoline and those that use E10/BOBs that take advantage of the 1 psi waiver for E10 would be subject to additional compliance demonstration requirements, potentially including per-batch RVP testing consistent with their ability to affect EFF quality. However, bulk blenders would only choose to accept the additional regulatory burden that accompanies the increased blending flexibility if there was an economic advantage to do so. We anticipate that the opportunity to use relatively low cost natural gasoline as an EFF blendstock could result in a significant cost savings in the production of EFF, while minimizing the regulatory burden and ensuring that EFF quality supports the EPA's environmental goals.
EFF bulk blender-refiners could demonstrate compliance with the proposed sulfur and benzene specifications and CHONS requirement by maintaining PTDs showing that they used only the approved blendstocks. Since the sulfur and benzene content of blended fuels is directly proportional to the sulfur and benzene content in the blendstocks used and bulk blenders would be limited to using certified blendstocks to manufacture EFF that meet applicable average and cap sulfur and benzene standards, we could be assured of compliance with the sulfur and benzene specifications for EFF without requiring per-batch testing.
However, the nonlinearity in the RVP of ethanol blended fuels means that additional provisions would be needed for EFF bulk blender-refiners to demonstrate compliance with the proposed maximum RVP standards for EFF from May 1 through September 15 for parties upstream of retail and WPC facilities. We are proposing several paths that EFF bulk blender-refiners could use to demonstrate compliance with the proposed maximum RVP requirements:
• EFF bulk blender-refiners that use only gasoline and BOBs that are compliant with the applicable regional RVP specifications without benefit of the 1 psi waiver for E10 could demonstrate compliance simply by maintaining the PTDs for the blendstocks used.
• EFF bulk blender-refiners that use certified natural gasoline EFF blendstock (in addition to gasoline/BOBs) or those that use gasoline/BOBs that take advantage of the 1 psi waiver for E10 as EFF hydrocarbon blendstocks could demonstrate compliance by either:
○ Conducting per-batch RVP testing, or
○ Using an RVP compliance tool.
To the extent per-batch RVP testing is used rather than the RVP compliance tool, we request comment on the potential to allow for less frequent testing provided that there was no change in the composition of the blendstocks or the blending recipe. Some parties may wish to perform per-
We are proposing that EFF bulk blender-refiners would be required to register with the EPA and provide annual reports on the EFF they produce. We expect that most EFF bulk blender-refiners would already be registered with the EPA as gasoline oxygenate blenders or ethanol producers. EFF bulk blender-refiners would also be required to provide PTDs for each batch of EFF they produce. The issuance of PTDs by fuel producers is common business practice.
Blender pumps produce a fuel with a particular ethanol content by drawing from two “parent blends” in different tanks at specified volume ratios. The blender pump can produce a mixture with an ethanol content anywhere between that exhibited by the parent blends in the two tanks. In most current cases, this involves E10 gasoline and E85. This proposal would replace the current gasoline refiner requirements for producers of E16-50 at blender pumps with requirements for the parent blends that may be used, including E51-83.
The properties of the blends produced are determined by those of the parent blends. Since sulfur, benzene, and non-CHONS elements blend linearly, compliance of the parent blends with the proposed specifications for these fuel parameters would ensure the compliance of blends produced at blender pumps. In the context of the average standards for benzene and sulfur that apply to gasoline, the benzene and sulfur concentrations of the EFF produced will vary, but should not increase on average. However, the nature of blending hydrocarbon fuels with ethanol is such that the RVP of the blend exhibits a highly nonlinear response. That is, the RVP of a blend of two fuels with two different ethanol contents diverges significantly from what one would predict based on a volume-weighted averaging of the RVPs of the two fuels. We conducted RVP modeling to evaluate the RVP of blends made at blender pumps using the parent blends that are commonly used. The results of this modeling indicate the use of the parent blends commonly used at blender pumps would result in mid-level ethanol blends that are expected to be within the evaporative emissions control capacity of FFVs.
We expect that E51-83 would be the EFF parent blend of choice at blender pumps so that it could be made available for sale, although other EFF blends could be used. We request comment on requiring that E51-83 be the EFF parent blend used at blender pumps. We believe that this limitation could provide additional quality control benefits for blender pumps while not removing any meaningful flexibility since using E16-50 as a parent blend is not currently a common practice at blender pumps. The EPA intends to monitor the RVP of blends produced at blender pumps and may propose additional controls in a later action if warranted.
Some blender pump operators have expressed interest in using DFE as a parent blend to produce EFF. Allowing the use of DFE as a parent blend component at blender pumps would provide additional flexibility to industry while meeting the EPA's environmental goals. The use of DFE as a parent blend could facilitate the direct marketing of DFE from ethanol plants to fuel retailers and allow retailers to separate RINs from DFE as it is used to create motor vehicle fuel. These practices could have the potential to reduce the retail cost of EFF. The use of DFE as a parent blend could also simplify the adjustment of blender pumps to produce various blend ratios of EFF compared to the use of EFF that may vary in ethanol content seasonally. When EFF is used as a parent blend, blender pumps must be readjusted each time a batch of EFF parent blend is delivered with a different ethanol blend ratio to ensure accuracy in the ethanol concentration of the blends produced at the blender pump.
However, storing DFE at blender pump facilities could result in increased fire safety concerns.
A summary of the blendstock requirements under the three proposed EFF certification options is contained in Table IV.D.4-1 below.
We are proposing that once EFF has been certified as meeting the proposed requirements, no additional blendstocks could be added downstream.
We are proposing a prohibition on commingling batches of EFF batches downstream of the production facility except at EFF blender pump-refiner facilities and retail/WPC facilities that dispense EFF from dedicated dispensers.
Fuel retailers and WPCs that make E15 at blender pumps using E85 as a parent blend are currently subject to all of the requirements that apply to refiners producing gasoline from crude oil, including registration, reporting, and per-batch testing. This is due to the fact that such blender pump operators are mixing non-gasoline (E85) with gasoline (E0 or E10). However, the application of these requirements to fuel retailers and WPCs is impractical. For example, it is infeasible for fuel retailers and WPCs to conduct laboratory tests on each batch of E15 produced (
Since the proposed requirements for EFF parallel those for gasoline, the use of EFF that meets the proposed requirements as a parent blend with compliant gasoline as the other parent blend would ensure that E15 made at blender pumps is compliant with the gasoline sulfur, benzene, and CHONS requirements. This is due to the linear blending characteristics of fuel sulfur, benzene, and CHONS content. The situation is analogous to commingling two previously certified gasolines, which does not entail any additional compliance demonstration requirements.
However, the non-linear RVP blending characteristics for gasoline-ethanol blends pose unique issues regarding RVP compliance for E15 made at blender pumps from June 1 through September 15 when gasoline RVP requirements apply at retail and WPCs. Blenders of E15 in conventional gasoline areas (both at blender pumps and at terminals) have typically not been able to make E15 that is compliant with summertime RVP requirements due to the unavailability of sub-RVP blendstocks. The gasoline blendstocks that are available in conventional gasoline areas are typically formulated to produce E10 with the 1 psi RVP waiver since it has not been economical for lower RVP gasoline blendstocks to also be made available that would be suitable to make E15.
We are proposing that from September 16 through May 31, all E15 gasoline blender pump-refiners, regardless of where they are located, could demonstrate compliance with the gasoline refiner requirements using the same approach that we are proposing for EFF blender pump-refiners—by maintaining PTDs that show that the parent blends used to make E15 (
We are proposing that EFF blender pump-refiners could demonstrate compliance with the proposed RVP requirements for EFF from June 1 through September 15 by maintaining PTDs that show the parent blends used were certified upstream of the blender pump-refiner as meeting local RVP
A similar approach for E15 can be used in many areas depending on whether the 1 psi waiver for E10 applies.
However, in conventional gasoline areas where the 1 psi waiver does apply, E15 made at blender pumps using E10 and EFF that meets the proposed RVP requirements would not be compliant with the applicable RVP requirements for gasoline. Therefore, in conventional gasoline areas where the 1 psi waiver for E10 applies, we are not proposing to allow blender pump-refiners of E15 that use E10 as a parent blend to meet their gasoline refiner requirements using PTDs for the parent blends used from June 1 through September 15.
In all areas, E15 produced at blender pumps using E0 and EFF meeting the applicable RVP requirements would not be in compliance with the applicable RVP requirements for E15. Therefore, we are not proposing to allow blender pump-refiners of E15 that use E0 as a parent blend to meet their gasoline refiner requirements from June 1 through September 15 by using PTDs for the parent blends used. Our proposal regarding the demonstration of compliance of blender pump-refiners of E15 with the RVP requirements for E15 is summarized in the Table IV.E-1 below.
As a result of the difficulty blenders face in locating sub-RVP blendstocks for use in making E15 that is compliant with the gasoline RVP requirements in areas where the 1 psi waiver for E10 applies, the EPA received requests for clarification about whether relabeling E15 as for use only in FFVs would exempt E15 from gasoline RVP requirements from June 1 through September 15. All gasoline, including E15, is subject to all of the requirements applicable to gasoline because of its formulation, not because of its end use. These requirements cannot be circumvented by relabeling. Allowing a fuel to be exempted from fuel quality requirements simply based on a statement of its intended use would undermine the EPA's ability to assure compliance with fuel quality requirements. In situations where E15 blenders could not locate sub-RVP blendstocks to facilitate compliance with the applicable gasoline RVP requirements, they could adjust the ethanol blend ratio to produce an EFF blend such as E20 from June 1 through September 15. Such producers of E20 or other EFF blends would be compliant with the proposed RVP requirements for EFF if they observed the proposed parent blend requirements for EFF blender pump-refiners. Such E20 producers would also be required to comply with the other proposed requirements for EFF blender pump-refiners and to appropriately label the fuel.
Some retailers may also be interested in producing E10 using E0 and EFF as parent blends at blender pumps. We seek comment on the need for, and means of, facilitating this practice without triggering the batch sampling testing requirements that apply to a gasoline refiner. The means of assuring compliance of E10 made at blender pumps using E0 and EFF with the sulfur, benzene, and CHONS requirements for gasoline should parallel those proposed above for blender pump-refiners of E15. However, because of the limited blending accuracy for blender pumps, we are not confident of the means to assure compliance with the gasoline volatility requirements for E10, particularly in areas where the 1 psi waiver for E10 does not apply, as well as in areas where the waiver does apply.
Registration, reporting, and recordkeeping requirements are necessary components to ensure that any fuels program is effectively implemented. This proposal includes registration, reporting, and recordkeeping requirements for each class of party tailored to their specific activities related to the production of EFF and E15 produced at blender pumps.
We are proposing that EFF full-refiners and importers, EFF bulk blender-refiners, and certified natural gasoline EFF blendstock refiners and importers register with the EPA prior to the production of EFF or natural gasoline EFF blendstock. Since downstream parties (
For registration, we are proposing to use the same basic forms that previous fuels programs have used. These forms are well-known in the regulated community and are simple to fill out. With the exception of certified natural gasoline EFF blendstock producers, we anticipate that most parties will already be registered under our existing fuel standards. Upon receipt of a completed registration form, the EPA would issue a unique 4-digit company identification number and a unique 5-digit facility identification number. As with existing fuels programs, these numbers would be required for all reports submitted to the EPA and for applicable PTDs.
Registrations would not expire and would not have to be renewed; however, we are proposing that registered parties would be responsible for notifying us of any change to their company or facility information.
An entity's registration would include a corporate name and address (including the name, telephone number, and email address of a corporate contact); and, for each facility operated by the entity:
• Type of facility (
○ Registrations for certified natural gasoline EFF blendstock refineries would be limited to natural gas processing plants and crude oil refineries.
• Facility name.
• Physical location.
• Contact name, telephone number, and email address.
These proposed registration requirements would be similar to those currently required for gasoline refiners and importers. The EPA has had success with these requirements and believes that they are appropriate for parties involved in the manufacture of EFF. However, there may be some additional registration requirements that would prove useful to ensure that parties involved in the manufacture of EFF make compliant fuels. Although we are not proposing any additional registration requirements on EFF refiners and importers, EFF bulk blender-refiners, and certified natural gasoline EFF blendstock refiners and importers compared to what we have historically required of gasoline or diesel refiners and importers, we seek comment on whether there are any other registration requirements that we should impose on these parties.
We are proposing to require parties involved in the manufacture of EFF to submit annual reports demonstrating their compliance with the EFF standards. Based on our experience with existing gasoline programs, we believe that requiring annual reports containing individual batch data would provide an effective means of monitoring compliance with the EFF standards.
Consistent with other fuel program annual reporting requirements, we are proposing that reports would be due annually on March 31. Since the EFF requirements are different for the proposed three broad categories of parties, there would be different reporting requirements for EFF full-refiners and importers, EFF bulk blender-refiners, and natural gasoline EFF blendstock refiners and importers.
For EFF full-refiners and importers, we are proposing that they submit annual batch level reports with sulfur, benzene, and ethanol content, as well as RVP, consistent with forms and procedures already used by gasoline refiners and importers. EFF full-refiners and importers would also have to demonstrate annual compliance with average sulfur and benzene content standards similar to gasoline refiners and importers. Although we are not proposing to have other fuel parameters reported by batch to the EPA that are currently required to be reported for gasoline (
We are proposing that EFF bulk blender-refiners would be required to submit an annual report that includes the volume, ethanol concentration, and blendstocks used (
Finally, for natural gasoline EFF blendstock refiners and importers, we are proposing similar reporting requirements for those outlined above for EFF full-refiners and importers. Since natural gasoline EFF blendstock refiners and importers would be required to meet per-gallon cap sulfur and benzene requirements, natural gasoline EFF blendstock refiners and importers would also have to report additional information to ensure that
Since most of this information is already required of some gasoline refiners, existing reporting forms and procedures for gasoline refiners should also be applicable to natural gasoline EFF blendstock refiners and importers with minor modification. We seek comment on whether we should require any additional reporting from natural gasoline EFF blendstock refiners and importers.
Consistent with existing CBI requirements, all refiners and importers of EFF and natural gasoline EFF blendstock can claim information submitted to the EPA as CBI. Parties making such a claim would be required to follow all reporting guidance and clearly mark the information being claimed as proprietary. The EPA would treat information covered by such a claim in accordance with the regulations at 40 CFR part 2, and other EPA procedures for handling proprietary information.
Consistent with current EPA fuels programs, we are proposing that EFF full-refiners and importers, EFF bulk blender-refiners, blender pump-refiners, and natural gasoline EFF blendstock refiners and importers would be required to retain all records that demonstrate compliance with applicable EFF and gasoline requirements. We are proposing that all of these parties would also be required to keep records of all bills of lading, PTDs, invoices or other commercial documents relating to gasoline, ethanol, natural gasoline EFF blendstock, or any other blendstock used to make EFF, and records of any quality assurance plans (QAPs). Records would need to be retained for five years consistent with other EPA fuels programs. We are proposing that records would be made available to the EPA on request. We are also proposing that if electronic records are kept, hard copies should be made available upon request.
Since several parties would be subject to different EFF requirements, we are proposing some specific requirements on different individual parties. For blender pump-refiners, we are proposing to require that records related to the calibration of blender pumps be kept. Most, if not all, retail stations are already subject to state weights and measures programs that require the calibration of fuel dispensers to be tested periodically. These calibrations are important to determining whether blender pump-refiner requirements are in fact being met by all gasoline-ethanol blends manufactured through a blender pump. We are not proposing specific calibration requirements for blender pumps because we believe that it is most appropriate for such requirements to be established by state weight and measure programs.
For EFF bulk blender-refiners, the demonstration that a particular batch of EFF would meet appropriate EFF fuel quality standards is based primarily on recordkeeping and QAPs. Therefore, it is paramount that appropriate records be kept and that attest engagement requirements are in place.
We are proposing that refiners and importers utilize the following sampling and test methods for measuring the fuel parameter properties of sulfur, benzene, oxygenate, RVP, 90 percent distillation point, and final boiling point for EFF and natural gasoline EFF blendstock. We are also proposing sample retention requirements for EFF and natural gasoline EFF blendstock. Table IV.F.2-1 below lists the ASTM standard practices that we are proposing.
We are proposing that refiners and importers of EFF and natural gasoline EFF blendstock utilize the following ASTM standard practices when sampling EFF and natural gasoline EFF blendstock. We are proposing that when refiners and importers manually sample EFF and natural gasoline EFF blendstock, they utilize ASTM D4057. We are proposing that when refiners and importers sample EFF and natural gasoline EFF blendstock by an automated sampling method, they utilize ASTM D4177. We are proposing that when refiners and importers sample EFF and natural gasoline EFF blendstock for volatility measurements, they utilize ASTM D5842. Finally, we are proposing that when refiners and importers mix and handle EFF and natural gasoline EFF blendstock for compliance measurements, they utilize ASTM D5854.
We are proposing that EFF full-refiners and importers and natural gasoline EFF blendstock refiners and importers measure sulfur content. Currently our regulations for the measurement of sulfur content in gasoline at 40 CFR 80.46 designates ASTM D2622 as the primary test method. For consistency's sake, we are proposing ASTM D2622 as the designated primary test method for measuring the sulfur content of EFF and natural gasoline EFF blendstock. We are also proposing six alternative test methods for the measurement of sulfur content of EFF and natural gasoline EFF blendstock: ASTM D1266, ASTM D3120, ASTM D5453, ASTM D6920, ASTM D7220, and ASTM D7039, provided that their test results are correlated to ASTM D2622. Of the test methods discussed here for measuring the sulfur content of EFF and natural gasoline EFF blendstock, we believe ASTM D2622 is the most precise test method.
We are also proposing that EFF full-refiners and importers and natural gasoline EFF blendstock refiners and importers measure benzene content. Currently our regulations for the measurement of aromatic content in gasoline at 40 CFR 80.46 designates ASTM D5769 as the primary test method. ASTM D5769 also measures the benzene content of gasoline. For consistency's sake and since ASTM D5769 also measures benzene content, we are proposing ASTM D5769 as the designated primary test method for measuring the benzene content of EFF and natural gasoline EFF blendstock. We are also proposing the allowance of three alternative test methods for the measurement of benzene content of EFF and natural gasoline EFF blendstock: ASTM D3606, ASTM D5580, and ASTM D6730, provided that their test results are correlated to ASTM D5769. Since ASTM D3606 has the potential for interference between ethanol and benzene when ethanol is present in the fuel sample, we do not believe ASTM D3606 is the best candidate to be the designated primary test method for EFF
We are also proposing that EFF bulk blender-refiners and blender pump-refiners measure oxygenate content as part of the proposed EFF survey program. Currently our regulations for the measurement of oxygenate content in gasoline at 40 CFR 80.46 designates ASTM D5599 as the primary test method. For consistency's sake, we are proposing to designate ASTM D5599 as the designated primary test method for measuring the oxygenate content of EFF. We are also proposing for the allowance of one alternative test method for oxygenate content measurement of EFF: ASTM D4815, provided that its test results are correlated to ASTM D5599.
We are also proposing that EFF full-refiners and importers, EFF bulk blender-refiners, and natural gasoline EFF blendstock refiners and importers measure RVP. Currently our regulations for the measurement of RVP in gasoline at 40 CFR 80.46 designates ASTM D5191 as the primary test method. For consistency's sake, we are proposing to designate ASTM D5191 as the designated primary test method for measuring the RVP of EFF and natural gasoline EFF blendstock. We are also proposing for the allowance of two alternative test methods for the RVP measurement of EFF and natural gasoline EFF blendstock: ASTM D5482 and ASTM D6378, provided that their test results are correlated to ASTM D5191.
Finally, we are also proposing that natural gasoline EFF blendstock refiners and importers measure the 90 percent distillation point and final boiling point of natural gasoline EFF blendstock. Currently our regulations for the measurement of the distillation point of gasoline at 40 CFR 80.46 designates ASTM D86-12 as the primary test method. For consistency's sake, we are proposing to designate ASTM D86-12 as the designated primary test method for measuring the 90 percent distillation point and final boiling point of natural gasoline EFF blendstock.
All of the test methods discussed here do not have established precision estimates for repeatability or reproducibility that would enable the EPA to propose Performance-Based Measurement System (PBMS) requirements for these analytical test methods. Once these estimates have been established by ASTM, at that time the EPA may propose PBMS requirements for the measurement of sulfur, benzene, oxygenate, RVP, 90 percent distillation point, and final boiling point of EFF and natural gasoline EFF blendstock. We welcome comment on our proposed sampling and test methods.
The EPA is also taking comment on whether we should establish Performance-Based Analytical Test Method Approach (PBATMA) requirements for the parameters of sulfur, benzene, distillation point, oxygenate content, and RVP in EFF and natural gasoline EFF blendstock. The EPA envisions that sulfur would fall under the absolute fuel parameter category for PBATMA where the precision criteria
As an alternative to per-batch RVP testing, we are proposing that EFF bulk blender-refiners that use natural gasoline to produce EFF could use an RVP tool to demonstrate compliance with the proposed maximum RVP specifications for EFF.
Equations 8 and 11 were modified from those in the referenced SAE paper by replacing the term “gasoline” with “hydrocarbon” to reflect that we are proposing that the RVP tool could be used when natural gasoline (and BOBs) are used as EFF blendstocks as well as gasoline. The proposed RVP compliance tool was developed based on data from ethanol blends made with gasoline as the hydrocarbon blend component.
There is some concern regarding the representativeness of the proposed RVP compliance tool when natural gasoline is used as a blendstock because of the low aromatic content of natural gasoline relative to gasoline/BOBs and the effect of aromatic content on the RVP of ethanol blends. However, we believe that the proposed tool would be suitable to cover the use of natural gasoline as an EFF blendstock. Because of the characteristics of natural gasoline, including its typical lower aromatic concentration, we anticipate that the proposed RVP compliance tool would tend to slightly overestimate the actual RVP of blends made using natural gasoline rendering its use somewhat conservative. The EPA is currently conducting work to test the RVP of ethanol blends made with natural gasoline. The results of this study will be used to validate that the proposed RVP compliance tool provides accurate results for blends that contain natural gasoline. If the results of this study indicate that the proposed tool needs to be amended to accurately reflect the RVP blending properties of natural gasoline, the EPA would modify it in a later action.
The RVP of unoxygenated gasoline, BOB, and/or natural gasoline EFF blendstock used to produce the EFF would be volume weighted to arrive at a value for the RVP of the mixture of the hydrocarbon blend components for use in equations 8 and 11. If DFE is used as an EFF blendstock rather that undenatured ethanol, the denaturant would also be included in the volume weighted calculation to arrive at a value for the RVP of the mixture of the hydrocarbon blend components used in equations 8 and 11. We expect that in most cases EFF would be produced at product terminals and that DFE would be used as a blendstock. EFF bulk blender-refiners that are also ethanol producers would have the option to use undenatured ethanol in blending EFF that they manufacture at their production facilities. For the purpose of calculating the inputs for the RVP compliance tool regarding the RVP and volume percent of the hydrocarbons in the EFF blend, it could be assumed that the DFE used as a blendstock contains 3 volume percent denaturant at 15 psi RVP. The volume percent ethanol input to the RVP compliance tool equations would also be assumed to be 97 percent of the volume percent of the DFE used as a blendstock.
We believe that this approach would provide a conservative estimate of the effect of the ethanol denaturant on the volatility of the finished EFF blend. Ethanol denaturant concentration is limited to a maximum of 3.0 volume percent beginning January 1, 2017, pursuant to the requirement of the Tier 3 final rule.
We are proposing that EFF bulk blender-refiners would be required to participate in the proposed EFF quality survey. We expect that participation in this survey would provide needed assurance that the RVP compliance tool is being used appropriately, as well as providing needed assurance that other EFF requirements are being satisfied.
We request comment on the above RVP compliance tool, any alternative RVP correlations that might be more accurate, and any data that might be available to enhance its accuracy. We also request comment on whether the proposed RVP blending compliance tool could be extended to cover the use of butane and/or pentane as an EFF blendstock if the use of these blendstocks was allowed.
The EPA is proposing several changes and additions to the existing PTD requirements to provide the information needed for fuel providers to properly manufacture or blend EFF. The EPA has previously established similar requirements for PTDs for E10 and E15 to help ensure downstream compliance
Under the current regulations, the transferor of gasoline-ethanol blends with ethanol content above 15 percent is required to provide to the transferee information on ethanol concentration of the blend by the following statement: “EXX—Contains no more than XX% ethanol.”
We are proposing to add new PTD requirement for transfers of EFF. The general requirements would be similar to that of gasoline, where any person that transfers EFF would be required to provide PTD information including the name and address of the transferor and transferee, the volume of EFF being transferred, the location of EFF at the time of transfer, the date of transfer, and the approximate ethanol concentration as discussed above. The transferor would also be required to provide a statement on the PTD that indicates its suitability or lack thereof for use as a blendstock to manufacture EFF in a blender pump. As discussed earlier, there are a number of paths to manufacture EFF and the challenges in demonstrating compliance with the RVP standard are greatest for blender pumps, given the non-linear RVP blending characteristics of potential blendstocks. To resolve this concern, we are proposing to list the blendstocks that can be used in blender pumps to make EFF and to require a statement on the PTD that states whether the blendstock is suitable for use in a blender pump and meets the RVP requirements.
Under the proposed rule, blender pumps can manufacture EFF by blending no more than two blend components: A high ethanol content blend component and a high hydrocarbon content blend component. The components will primarily vary based on two factors: Whether the blendstock is being used in a CG or RFG area and whether it is between June 1 and September 15.
We are proposing to add a new PTD requirement for the transfer of certified natural gasoline EFF blendstock. The PTD would require general information such as the name and address of the transferor and transferee, volume of the blendstock being transferred, location of the blendstock at the time of the transfer, and the date of the transfer. We are also proposing to require reporting the RVP on the PTD to facilitate downstream blending by alleviating the need for additional downstream testing and to minimize any improper commingling. The natural gasoline EFF blendstock refiner or importer may choose to either conduct per-batch sampling to determine the RVP or use a default RVP value of 15 psi.
We are also proposing to require a statement on the PTD prohibiting the use of natural gasoline EFF blendstock as a blendstock at blender pumps and its sale as conventional blendstock for oxygenate blending (CBOB) or reformulated blendstock for oxygenated blending (RBOB). Natural gasoline is known to be the higher temperature boiling components of natural gas liquids that is sometimes used as a denaturant for ethanol. It is also utilized in producing EFF since it is conveniently stored at the plant for its denaturant use and is considerably less expensive than CBOB and RBOB. Yet natural gasoline is known to have a higher RVP than CBOB or RBOB, so its use may hinder downstream RVP compliance. As explained above, EFF blender pump-refiners are similar to full-refiners in that they have the ability to manufacture EFF, but do not have the same quality assurance requirements. Accordingly, we are proposing that the natural gasoline EFF blendstock be prohibited from use as a blendstock at blender pumps. Furthermore, we are proposing to require a statement to distinguish natural gasoline EFF blendstock from other blendstocks (such as CBOB or RBOB) to prevent any confusion for downstream parties. We are proposing to require a statement that it cannot be used as CBOB or RBOB or blended into CBOB, RBOB, or gasoline without meeting all requirements applicable to refiners. This statement would minimize any confusion for downstream parties and help ensure that certified natural gasoline EFF blendstock is not used as a gasoline blendstock.
We are proposing attest engagement requirements for EFF full-refiners and importers, EFF bulk blender-refiners, and certified natural gasoline EFF blendstock refiners and importers using the procedures used in other EPA fuels programs for attest engagements. We believe that attest engagements are particularly important for EFF bulk blender-refiners. Having an independent auditor review blending records to ensure that EFF made by bulk blender-refiners meet applicable EFF requirements would help ensure compliance, given the reduced sampling, testing, and reporting requirements. Attest engagements would also help ensure applicable EFF requirements are met, similar to how attest engagements help assure compliance for fuel manufacturers in other EPA fuels programs.
We are also proposing affirmative defense requirements for parties that manufacture, distribute, and sell EFF. These provisions would allow parties that manufacture, distribute, or sell EFF to help establish affirmative defenses against potential violations of the proposed EFF requirements if all applicable conditions are met. These proposed potential affirmative defenses are analogous to those provided to other parties in other EPA fuels programs.
The violation and penalty provisions applicable to this proposed EFF program would be very similar to the provisions currently in effect in other fuels programs. We are proposing that EFF and natural gasoline EFF blendstock downstream violations follow the same presumptive liability approach used in other fuel programs. We request comment on the need for additional attest engagement, violation, penalty, or any other compliance and enforcement related provisions to the proposed EFF and natural gasoline EFF blendstock requirements.
Based on our experience with our past fuel standards, we are proposing a sequence of start dates for compliance depending on the point in the fuel production and distribution system. We are proposing that the proposed requirements for EFF would apply to EFF full-refiners and bulk blender-refiners beginning January 1, 2018. EFF full-refiners and EFF bulk blender-refiners would be required to submit their registration applications to the EPA by November 1, 2017, or 2 months prior to producing EFF. To allow sufficient time for certified natural gasoline EFF blendstock to be made available to EFF full-refiners and bulk blender-refiners, we are proposing that the requirements for certified natural gasoline EFF blendstock would apply beginning December 1, 2017. Producers of certified natural gasoline EFF blendstock would be required to submit their registration applications to the EPA by October 1, 2017, or 2 months prior to producing certified natural gasoline EFF blendstock.
We are proposing that the proposed requirements for EFF would apply at retail and WPC facilities beginning February 1, 2018. We are proposing that the provisions for E15 blender pump retail and WPC facilities would likewise be effective beginning February 1, 2018. This would provide one month between the date when upstream producers of EFF are required to comply and the date for retail and WPC compliance to allow time for EFF retail tank turnover. This time for retail/WPC tank turnover would be needed for blender pumps that produce E10/E15 as well as those that produce E16-50 using EFF as a parent blend. We anticipate that retailers and WPC facilities would draw down their storage tank volumes and manage deliveries to facilitate compliance on February 1, 2018. We request comment on whether these proposed compliance dates would provide sufficient time for the various parties in the EFF production and distribution system to prepare for compliance.
We are planning on allowing at least 4 months after the publication of the final rule that results from this action before the EFF requirements and gasoline blender pump provisions would apply at retail and WPC facilities. If publication of the final rule is delayed, we would adjust the compliance dates for the various parties in the EFF production and distribution system discussed above to maintain a similar sequenced compliance schedule.
Under the volatility control provisions for conventional gasoline, retail outlets and WPC facilities are required to comply with gasoline RVP requirements from June 1 through September 15 of each year.
The same seasonal environmental concerns exist regarding the control of evaporative emissions for FFVs as exist for gasoline vehicles. Therefore, we are proposing that EFF retail and WPC facilities would be required to comply with the proposed RVP standards for EFF from June 1 through September 15 each year in parallel with the requirements for gasoline. We are also proposing that all facilities upstream of retail and WPC facilities would be required to comply with the proposed RVP requirements for EFF from May 1 through September 15 each year in parallel with the gasoline RVP requirements. We believe that this compliance schedule should provide sufficient time for EFF retail and WPC tank turnover provided that EFF retailers and WPC carefully manage their tank volume and delivery schedules. However, we are requesting comment on whether an earlier compliance date would be appropriate for parties upstream of retail and WPC facilities given the historically longer turnover time for EFF retail tanks.
The proposed compliance dates discussed above are summarized below in the Table IV.F.6-1.
CAA section 211(o)(2)(A)(i) requires that the EPA establish a regulatory program to ensure that transportation fuel contain specified volumes of renewable fuel. In the regulatory program enacted as part of the RFS2 final rule,
At the time of the RFS2 final rule, E51-83 was not included with gasoline and diesel as a fuel that incurs an RVO, despite the fact that it can be used as a transportation fuel and it has some non-renewable content. Gasoline is the only non-renewable material that currently can be used to make E51-83 EFF while ensuring that it meets the gasoline sub-
In the years since 2010, there has been increasing interest in the use of natural gasoline as an E51-83 blendstock. Since E16-50 blends are produced at blender pumps using E51-83 as one of the parent blends, such natural gasoline would also be a component of E16-50 blends. As stated before, gasoline is the only non-renewable material that currently can be used to make E51-83 EFF, and natural gasoline, which is typically extracted from the condensates produced from natural gas wells, is not considered to be gasoline under our current regulations. This proposal contains provisions to allow the use of natural gasoline as an EFF blendstock.
Since under our current regulations natural gasoline is not considered to be finished or unfinished gasoline that will eventually be used in the transportation sector, it does not currently incur an RVO under the RFS program. However, by replacing the finished and unfinished gasolines that had formerly been used to produce E16-83 with natural gasoline, it is appropriate to consider whether the RFS regulations should be modified to add natural gasoline used to produce E16-83 to the list of fuels that incur an RVO. This proposal also contains provisions to regulate all E16-83 blends as EFF rather than to continue to treat E16-50 blends as gasoline, thereby providing additional impetus to the consideration of whether natural gasoline used in EFF blends should be added to the list of fuels that incur an RVO.
Under the RFS regulations, the party that first produces or imports a transportation fuel is generally the party that incurs the RVO for the non-renewable portion of that transportation fuel. If EPA were to require all natural gasoline used to make EFF to incur an RVO, there would be a different point of obligation for certified versus uncertified natural gasoline used as an EFF blendstock. For certified natural gasoline EFF blendstocks, the party incurring the RVO would be the producers or importers, consistent with producers and importers of all gasoline and diesel. For uncertified natural gasoline EFF blendstock, however, the party incurring the RVO would be the party that blends DFE with the uncertified natural gasoline EFF blendstock to produce EFF, since the natural gasoline would not have been designated or treated as an EFF blendstock upstream at the point of production or importation. EFF is generally produced by blenders and ethanol producers that would typically not produce any other fuels that would incur an RVO. Thus, the imposition of an RVO on the producer of EFF would make certain parties responsible for satisfying an RVO that have not had such obligations to date. The EFF producer would need to quantify and track volumes of natural gasoline separately from gasoline and BOBs used to produce EFF. The EFF producer would also be required to acquire and retire an appropriate number of RINs to meet their obligation under the RFS program. There would be both practical and economic impacts on EFF producers that might discourage its expansion in the marketplace.
While in general we continue to believe that all non-renewable transportation fuel should incur an RVO, we also believe that expanding opportunities for the use of EFF is an important goal of the RFS program. Since imposing an RVO on EFF producers that use natural gasoline could potentially conflict with that goal, it may not be appropriate to do so at this time. Moreover, the volume of EFF is currently significantly smaller than the volume of other non-renewable transportation fuels, and is expected to remain so for some time. Based on these considerations, we are not proposing that natural gasoline used to make EFF would incur an RVO, but are instead proposing to defer the imposition of an RVO on parties making EFF with natural gasoline until such time as EFF produced using natural gasoline becomes a more substantial fraction of the transportation fuel pool. We seek comment on this issue and the option to defer the RVO obligation for this fuel.
During the Tier 3 public comment period, we received comments requesting that the EPA adopt labeling provisions for EFF fuels to help prevent the misfueling of EFF into gasoline-powered conventional vehicles.
Since the publication of the E15 misfueling mitigation rulemaking and the end of the Tier 3 public comment period, the FTC has finalized labeling requirements for EFF.
While this proposal focuses on establishing requirements for EFF quality, minor modifications to the E15 misfueling mitigation requirements at 40 CFR part 80, subpart N, are needed to accommodate the proposed EFF requirements. We are not reopening any other portions of subpart N, and are therefore not seeking comments on aspects of subpart N other than those described in this proposal.
We are proposing a restructuring of 40 CFR part 80, subpart N, to incorporate the proposed EFF requirements. In general, the E15 misfueling mitigation requirements are unchanged; however, some slight modifications to the E15 misfueling mitigation requirements would be necessary to incorporate EFF requirements. For example, we are proposing to change the PTD requirements for E15 misfueling mitigation in 40 CFR 80.1563 to be consistent with PTD requirements for the Tier 3 gasoline sulfur program and incorporate new language to help EFF blender pump-refiners comply with applicable EFF requirements. Additionally, consistent with PTD requirements in other EPA fuels programs, we are proposing to allow parties to submit alternative EFF PTD language for EPA approval, including E15 misfueling mitigation PTD requirements. This would allow all affected parties an opportunity to use
We are also proposing to add a definition for flexible-fuel engines and language that exempts flexible-fuel nonroad engines from the prohibition on the use of gasoline-ethanol blended fuels containing more than 10 volume percent ethanol since these engines have been certified on the use of EFF similar to FFVs. Although we have pointed out that the current regulatory requirements allow flexible-fuel engines to use EFF,
The EPA has a successful history of allowing regulated parties to participate in survey programs managed by an independent survey association as a way to decrease compliance costs for both regulated parties and the EPA. We recognize that many, if not all, EFF bulk blender-refiners and blender pump-refiners would have difficulty complying with the EFF full-refiner requirements, including sampling and testing, compliance reporting, recordkeeping requirements, and attest engagements. As a result, we have developed compliance systems for EFF bulk blender-refiners and blender pump-refiners that rely primarily on monitoring records as discussed above. Such systems, however, are subject to fraud and abuse without some means to verify their authenticity. As a result, we need some means of doing so for EFF. Based on past experience with our other fuel programs, we believe the least costly and most effective way of doing so is through in-use fuel quality surveys. As such, we believe that allowing EFF bulk blender-refiners and blender pump-refiners to verify compliance with the proposed EFF requirements through participation in a survey program and the use of appropriate blendstocks and parent fuels is appropriate. EFF bulk blender-refiners and blender pump-refiners would comply with the applicable EFF standards through the use of appropriate parent fuels and blendstocks and by contracting an independent survey association to conduct a survey of EFF manufactured through blender pumps and blended in bulk at terminals or at an ethanol production facility. The scope of the EFF blender pump survey program and specific design requirements for the survey program are discussed below.
The survey would be limited to collecting and analyzing samples of EFF for ethanol content, sulfur content, benzene content, and RVP (from June 1 to September 15) at EFF and blender pump retail stations. The proposed EFF requirements would impose a 10 ppm annual average sulfur standard, 95 ppm per-gallon sulfur cap, and 0.62 volume percent annual average benzene standard on all EFF. In lieu of requiring the sampling and testing of each batch to ensure compliance with the sulfur and benzene standards, the EPA is proposing to allow EFF bulk blender-refiners and blender pump-refiners the flexibility to comply with these standards by contracting with an independent survey association to randomly sample and test the EFF they manufacture. The EPA believes that most terminals, ethanol production facilities, and retail stations that make EFF would prefer to contract an independent survey association to conduct such a survey since it would be significantly cheaper than sampling and testing each batch of fuel for sulfur and benzene content.
As discussed earlier, determining the RVP resulting from commingling gasoline, ethanol, and natural gasoline is complicated for parties that are simply creating small batches of EFF.
The benzene and sulfur test results from these fuels would help ensure that EFF manufactured by an EFF bulk blender-refiner and the parent blends at an EFF blender pump-refinery (
The EPA is also proposing to require that EFF bulk blender-refiners participate in the survey as part of satisfying the alternative compliance provisions as EFF bulk blender-refiners. In order to ensure that the EFF produced by an EFF bulk blender-refiner met applicable EFF standards, all EFF retail outlets would need to be surveyed. Testing these fuels for regulated parameters would help ensure that EFF produced by bulk blender-refiners met standards.
We are not proposing to require that EFF full-refiners participate in the EFF survey program in addition to the other proposed requirements for EFF full-refiners. We believe that EFF full-refiners can demonstrate that their fuels would meet applicable EFF fuel quality standards through the sampling and testing of each batch of EFF at the point of production consistent with how gasoline refiners have done so in other EPA fuels programs. Historically, the EPA has never required that parties contract with an independent surveyor as the only means of demonstrating requirements. Compliance surveys have always been a compliance option for parties in lieu of conducting their own compliance assurance programs. Requiring all EFF refiners to participate in the survey would also blur the lines between the compliance options of being an EFF full-refiner or an EFF bulk blender-refiner and make the full-refiner option less attractive to parties that manufacture EFF. However, requiring EFF full-refiners to participate in the survey program would help spread out the compliance costs across all parties that manufacture EFF since the EFF survey would sample and test EFF from retail stations regardless of which party produced it. Therefore, although we are not proposing to require EFF full-refiners to participate in the EFF survey program, we seek comment on whether EFF full-refiners should be required to participate in the EFF survey program.
We recognize that the proposed EFF survey program overlaps significantly with the E15 survey program. The E15 survey program already regularly samples blender pump stations for the ethanol content of gasoline samples, with a focus on E15. Currently, most blender pump stations are selected for sampling and testing since these stations make up a bulk of the stations already offering E15 and are the most likely to offer E15 without satisfying E15 misfueling mitigation requirements. Additionally, some retail stations that market E85, but do not have blender pumps, are randomly selected as part of the E15 survey program. Since these stations are already being surveyed as part of the E15 survey program, we believe that responsible parties could integrate the proposed EFF survey program with the E15 survey to reduce the cost to industry. However, the proposed EFF survey program requirements are separate from the E15 survey requirements in the regulations and EFF bulk blender-refiners and blender pump-refiners may choose to have two different independent survey associations to conduct the E15 and EFF surveys.
We are proposing similar survey design elements for the EFF survey program as those used in other EPA fuels survey programs. The survey would be conducted by an independent survey association with the same independence requirements used in other fuels survey programs. The independent survey association would submit an annual plan to the EPA for approval that outlines how the EFF blender pump survey requirements would be met. These requirements would include how blender pump and EFF stations would be selected for sampling and testing, how samples would be procured, how samples would be tested for sulfur, benzene, RVP, and ethanol content, and how potential issues would be reported to the EPA. The survey association would have to also submit periodic and annual reports on aggregate survey results to the EPA. The survey association would be responsible for identifying blender pump and EFF station locations and providing those locations to the EPA on a regular basis. The survey association would also let the EPA know if any EFF bulk blender-refiner or blender pump-refiner fails to participate in the EFF survey consortium. Similar to other survey programs, the survey association would also have to provide proof of monies for the approved survey plan prior to the implementation of the annual EFF survey plan. Consistent with other EPA fuels survey programs, the EFF survey program would require four quarterly surveys.
We also are proposing a slightly different sample size determination methodology from those used in other EPA fuels survey programs for the EFF survey program. Since the EFF survey program needs to sample EFF produced by a bulk blender-refiner and distributed to all EFF stations (
For all EFF stations, the sample size determination methodology would be similar to those already required in other EPA fuels survey programs with one difference. Since the number of total EFF stations is still relatively small (around 3,000 stations), a finite population correction would be needed to account for the small population of EFF retail stations. Additionally, we are proposing a minimum number of samples for the survey of all EFF retail stations of 500 stations to account for the relatively low population of EFF retail stations. The EPA would reconsider the minimum sample size if the number of EFF retail stations increases substantially relative to the total number of fuel retail stations nationwide.
For the subset of EFF stations that make EFF via a blender pump, we believe a different sample size determination methodology is necessary due to the even smaller relative size of the population of blender pump stations. To date there have been a limited number of retail stations that own or operate blender pumps (we estimate 400 to 500), spread out over many states but focused primarily in the Midwest. Given the limited number of retail stations that currently own or operate blender pumps, we propose that the survey would be conducted at all blender pump stations each year until the number of retail stations with blender pumps exceeds 500 stations. This would mean that each retail station with a blender pump could expect to be sampled at least once per year. Once the number of stations with a blender pump exceeds 500 stations, the survey association would determine the number of retail stations to be sampled in accordance with appropriate sample size determination methodology.
Although we are not proposing a maximum number of samples, a maximum sample size could be used to limit the cost of the survey program since the number of retail stations that are needed to be sampled would depend on compliance rates determined by the previous survey period and the number of total retail stations with blender pumps. For example, in the ULSD Survey Program, we established a maximum number of samples at 9,600 to limit industry's potential cost.
We are proposing that the survey association use a method for collecting samples of EFF produced through a blender pump consistent with those specified in NIST Handbook 158. Since most E15 is currently produced by blending E10 with EFF via a blender pump, the EPA has encountered some challenges with collecting a valid sample due to the unique way that blended fuels are produced at blender pumps. The issue was that inconsistent ethanol content results occurred due to variation between the independent survey association and states' weights and measure offices. In order to address this issue, the EPA has worked with industry, the RFG Survey Association, and other affected stakeholders to
Unlike in our other fuel survey programs, we are proposing not to require that the samples at retail stations be stratified. The practical implication of not stratifying the sample is that the annual sample size of retail stations surveyed would be decreased.
We are proposing that the independent surveyor submit the survey plans to the EPA for approval no later than November 15 of the preceding year and that proof of monies be submitted to the EPA no later than December 15 of the preceding year. These dates are consistent with other EPA fuels survey programs and should provide enough time for an independent surveyor to submit plans and begin conducting the survey. It should be noted that responsible parties may only take advantage of the alternative compliance provisions for EFF bulk blender-refiners and blender pump-refiners if they participate in a survey program with an EPA-approved survey plan.
Although the EFF quality survey program would be required for EFF bulk blender-refiners and blender pump-refiners, we are proposing that other parties (
Even though the EFF quality survey program is similar to other EPA fuels program surveys, we are proposing some significant changes to the survey design to accommodate blender pumps and EFF stations. We believe that the proposed survey design can effectively help assure compliance without imposing unnecessary burden on responsible parties. However, we are interested if there are changes to the proposed EFF survey program that could improve its effectiveness in assuring compliance or further reduce costs for responsible parties. One option to reduce costs would be to find alternatives to ensuring compliance at the retail level without sampling and testing. For example, the independent surveyor could review the PTDs of parent fuels to ensure that EFF blender pump-refiners only received certified gasoline and EFF for EFF production through a blender pump. This PTD review could be less expensive than the sampling and testing of EFF and could replace some of the sampling that needs to occur under the proposed EFF survey program. The EPA is not proposing this option over concerns that retail stations may not wish to allow an independent surveyor to review their PTDs and thus diminish response rates in the proposed survey program. We seek comment on allowing independent surveyors to review PTDs in lieu of taking an EFF sample and testing it for compliance and whether there are any additional survey design changes that should be incorporated in the proposed EFF survey program.
The proposed provisions to allow the use of natural gasoline as a blendstock to produce EFF could reduce the cost of EFF and result in the increased use of ethanol to help meet the RFS mandates. However, the use of natural gasoline would also introduce complications, necessitate the substantial new provisions discussed in this proposal, and increase the EPA's burden to ensure that EFF meets environmentally protective standards. Accordingly, we are also seeking comment on implementing two alternative simpler programs to regulate EFF.
The first alternative would only allow the use of EPA-compliant gasoline, BOBs, and DFE as EFF blendstocks. This would parallel the current requirements in California while still expanding the allowable range of ethanol blends.
A number of the provisions in this proposal would remain unchanged under this simpler approach. For example, we would still propose to treat E16-50 in a similar way to other EFF blends that may only be used in FFVs (E51-83), and would defer consideration of requiring compliance with the F&FA program requirements for all EFF to a future action. The proposed EFF blender pump-refiner provisions would also remain the same.
Since parties that produce EFF would only be using DFE and EPA-compliant gasoline or BOBs, they would not have to conduct any sampling or testing to demonstrate compliance with any of the proposed requirements for EFF, including the RVP requirements. The only programmatic requirements for EFF bulk blender-refiners would be to register with the EPA, keep PTDs and other records regarding their blending activities, and submit simple annual reports with information regarding the EFF batches they produced during the year.
The second alternative would allow EFF producers to use certified natural gasoline EFF blendstocks in addition to certified gasoline and BOBs, but would not allow the use of uncertified natural gasoline EFF blendstocks. Thus, the EFF full-refiner certification option would no longer be included. There are several benefits of this proposed approach, as it would allow the increased use of natural gasoline to produce EFF, thereby reducing the costs, and would also assure that the overall emissions from EFF are no greater than emissions from the production of EFF with certified gasoline without the complications necessitated by the use of uncertified natural gasoline. The EFF full-refiner option would allow natural gasoline with higher benzene and sulfur levels to be used to produce EFF, provided that tests on the finished EFF demonstrated the same level of control as provided for gasoline under the current regulations. The added complexity under the EFF full-refiner option, which is needed to
We request comment on whether the increased flexibility of allowing the use of either certified or uncertified natural gasoline as an EFF blendstock justifies the EPA promulgating the previously discussed comprehensive compliance provisions and the increased burden of governmental oversight, or whether it would be more appropriate to implement one of the simpler programs described above.
FFVs have been manufactured and introduced into commerce for more than two decades and are typically designed to operate on gasoline and any gasoline-ethanol mixture of up to 83 percent ethanol. These fuels contribute to emissions of VOC and NO
When operating on gasoline, FFV emissions are minimized due to the existing gasoline content requirements (
The EPA is proposing to regulate EFF content pursuant to our authority under CAA section 211(c). We are proposing sulfur, benzene, and RVP controls for EFF based on both of the criteria in section 211(c). This section allows the EPA to establish a fuel control if at least one of the following two criteria is met: (1) The emission products of the fuel cause or contribute to air pollution that may reasonably be anticipated to endanger the public health and welfare;
Under the first criterion of CAA section 211(c)(1), we believe that EFF with current levels of sulfur, benzene, and RVP causes or contributes to ambient levels of ozone, PM and air toxics that endanger the public health and welfare. EFF containing sulfur at the current levels increases emissions of NO
The EPA has set National Ambient Air Quality Standards (NAAQS) for ambient concentrations of PM and ozone.
Ground level ozone pollution is typically formed through reactions involving VOC and NO
Natural gasoline can have high benzene content, potentially resulting in high levels of benzene in EFF. The EPA's Integrated Risk Information System (IRIS) database lists benzene as a known human carcinogen.
In sum, we are proposing that emission products of EFF will endanger public health and welfare. FFVs represent more than 6 percent of the current vehicle fleet and approximately 25 percent of new light duty vehicles produced in 2014. Given that FFVs tend to be newer vehicles that are driven more than older vehicles, FFVs account for nearly 8 percent of all light duty vehicle miles traveled in 2015.
Prior to adopting a fuel control based on a finding that the fuel's emission products contribute to air pollution that can reasonably be anticipated to endanger public health or welfare, under CAA section 211(c)(2)(A), the EPA must consider “all relevant medical and scientific evidence available, including consideration of other technologically or economically feasible means of achieving emission standards under [section 202 of the CAA].” The EPA has considered medical and scientific evidence as well as other technologically or economically feasible means of achieving emissions control using vehicle controls. The EPA's analysis of the medical and scientific evidence relating to the emissions impact from EFF is described in more detail in various documents cited earlier, including the MSAT rule, and the Ozone and PM NAAQS final rules and their associated Integrated Science Assessments (ISAs). The EPA has also satisfied the statutory requirement to consider “other technologically or economically feasible means of achieving emission standards under [section 202 of the CAA].” This provision has been interpreted as requiring consideration of establishing emission standards under CAA section 202 prior to establishing controls or prohibitions on fuels or fuel additives under CAA section 211(c)(1)(A).
We are also proposing requirements for sulfur content in EFF and RVP limits for EFF under the second criterion of CAA section 211(c). We believe that sulfur in EFF could significantly impair the emission-control systems expected to be in general use in FFVs and FFV engines. There are well documented studies on the impact of sulfur on emissions control performance of exhaust catalyst systems.
There are currently no specifications in 40 CFR part 80 for natural gasoline used as an EFF blendstock that would ensure that the resulting EFF is suitable for use in FFVs. Additionally, natural gasoline can have high sulfur content, potentially resulting in high levels of these harmful components in EFF that could impair the performance of FFV emissions control catalysts. As also previously explained, the EPA set vehicle and engines standards, under CAA section 202, in the recent Tier 3 rule that relied on sulfur reduction in gasoline. FFVs utilize the same aftertreatment catalysts as gasoline vehicles, which are adversely affected by sulfur in EFF in the same way as sulfur in gasoline. Therefore, we believe that control of sulfur in EFF to 10 ppm (the same as sulfur in gasoline) will significantly improve the efficiency of emissions control systems currently in use in FFVs and continue prevention of the substantial adverse effects of sulfur levels on the performance of such emissions control systems when they operate on any fuel.
We also believe that high RVP levels in EFF could impair FFV evaporative emissions control systems. FFVs are equipped with evaporative canisters similar to conventional gasoline vehicles. These canisters have limited storage abilities and fuel vapors must be “purged” each time the engine is operated. FFVs with properly designed evaporative control systems are equipped with purging systems that remove enough vapor as well as control fuel flow rates so that purged vapor does not increase emissions. They are also designed to regenerate their vapor storage capacity so that vapor can continue to be controlled. However, when FFVs are operated on EFF with RVP levels above the test fuels used during FFV certification the evaporative canisters on FFVs can be overloaded resulting in excessive evaporative emissions. Therefore, we believe that the RVP of EFF must be controlled to ensure that FFVs are not subjected to EFF that exceeds the RVP of test fuels used during FFV certification.
CAA section 211(c)(2)(B) requires that, prior to adopting a fuel control based on a significant impairment to vehicle emission-control systems, the EPA consider available scientific and economic data, including a cost benefit analysis comparing emission-control devices or systems which are or will be in general use that require the proposed fuel control with such devices or systems which are or will be in general use that do not require the proposed fuel control. As previously explained, there are existing emissions standards for FFVs and FFV engines under CAA section 202, including the MSAT evaporative emission standards applicable to diurnal and hot soak emissions for FFVs,
CAA section 211(c)(2)(C) requires that prior to prohibiting a fuel or fuel additive, the EPA must make a finding that such prohibition will not cause the use of another fuel or fuel additive “which will produce emissions which endanger the public health or welfare to the same or greater degree” than the prohibited fuel or additive. This finding is required by the CAA only prior to prohibiting a fuel or additive, not prior to controlling a fuel or additive.
The EPA is also proposing to regulate the elemental composition of EFF, as we believe that elements that poison (deactivate) vehicle emissions control catalysts such as anions or cations (
As also previously explained, there are currently no specifications in 40 CFR part 80 on the quality of natural gasoline used as EFF blendstock that would ensure that the resulting EFF is suitable for use in FFVs. Were natural gasoline used in EFF to contain non-CHONS elements (
CAA section 211(f) requires fuel and fuel additives introduced into commerce to be “substantially similar” to fuels or fuel additives used in certification. This requirement applies to all fuels used in motor vehicles, including FFVs. The term “substantially similar” is not defined in the CAA and has been interpreted and historically used to regulate the elemental content, molecular structure, and total concentration of fuel and fuel
We are proposing regulations under CAA section 211(f) that limit elemental composition of EFF to CHONS. We are proposing that parties must demonstrate the elemental composition of EFF using our authority under CAA sections 114 and 208 to establish and maintain records, and make reports.
CCS is a potentially important technology for reducing GHG emissions from stationary sources. As described in the final standards of performance for GHG emissions from new, modified, and reconstructed electric utility generating units (“NSPS for EGUs”), it is important to promote deployment and further development of CCS technologies that allow for meaningful reductions in CO
The EPA has received petitions under the RFS program to apply CCS to reduce the lifecycle GHG emissions associated with ethanol produced as renewable fuel.
In this action we are proposing registration, recordkeeping, reporting, and RIN generation requirements that the EPA would use if we were to allow CCS as a lifecycle GHG emissions reduction technology in the context of the RFS program. At this time, the EPA is not proposing to add a generally applicable CCS technology to an approved pathway in Table 1 to 40 CFR 80.1426, but instead will evaluate, on an individual basis, petitions that are received pursuant to 40 CFR 80.1416 that propose to use CCS. In this action we are proposing regulations that would generally govern the use of CCS if and when such a pathway is approved. Were a renewable fuel pathway involving use of CCS to be created in the future, use of the pathway in the context of the RFS program would remain voluntary and all other applicable existing RFS regulations would apply.
The EPA has already developed an effective and coherent regulatory framework to ensure the long-term, secure, and safe storage of large volumes of CO
The UIC Program is designed to ensure that injected CO
40 CFR part 98, subpart RR, of the GHGRP establishes an accounting framework for the geologic sequestration of CO
For the purposes of this proposed rulemaking, a facility is conducting geologic sequestration if it is reporting under 40 CFR part 98, subpart RR.
This rulemaking proposes and seeks comment on a series of registration, recordkeeping, reporting, and additional requirements associated with the use of CCS as a lifecycle GHG emissions reduction technology in the context of the RFS program. The proposed requirements would apply only to renewable fuel producers that seek to achieve the GHG reductions necessary to qualify for a given renewable fuel pathway by using CCS as part of the renewable fuel production process. By building on the foundation established in the GHGRP and UIC Program, this proposal seeks to contribute to a consistent approach across the EPA for facilities that use CCS. It is important to note that in this action the EPA specifically seeks comment only on the proposed requirements for use of CCS as part of the RFS program. This proposed action is not seeking comments on the recently finalized NSPS for EGUs, nor does it seek comment on any of the requirements under the UIC Program or the GHGRP. Any such comments that are submitted on those programs will be considered beyond the scope of this rulemaking. Furthermore, EPA is not proposing to consider use of CCS in any particular application in the RFS program at this time, and any comments suggesting its application in particular renewable fuel production pathways will also be considered beyond the scope of this rulemaking.
A renewable fuel producer seeking to use a pathway involving CCS would be required to submit a CCS plan for review and approval by the EPA's Office of Transportation and Air Quality as part of the facility registration requirements under 40 CFR 80.1450. The CCS plan would contain fundamental information regarding various elements of a given CCS project, including information related to sequestration processes and energy usage. This information is needed for the EPA to determine the amount of geologically sequestered CO
The EPA is proposing that the CCS plan the renewable fuel producer submits at registration would contain the following information:
1. A statement of affirmation by the sequestration facility that the sequestration facility will inject CO
2. A statement of affirmation by the renewable fuel producer using a method approved by EPA—as part of the
3. If the CO
a. The sale or transfer of CO
b. The duty of the sequestration facility to inject the CO
c. The geologic sequestration facility's duty to notify the renewable fuel producer of CO
d. Acknowledgement of the geologic sequestration facility's duty to help the renewable fuel producer develop a remediation plan within 30 days of the EPA being notified by the renewable fuel producer of a surface leak, providing information related to the date(s) the surface leak occurred, the GHGRP facility identification number of the geologic sequestration facility, a detailed description of how the leak occurred, the amount of CO
e. Acknowledgement of the geologic sequestration facility's duty to notify the renewable fuel producer within 30 days of its annual submission to the EPA of all reports required pursuant to 40 CFR part 98 subpart RR.
f. Acknowledgement of the geologic sequestration facility's duty to notify the renewable fuel producer if the sequestration facility submits a request pursuant to 40 CFR 98.441 for discontinuation of reporting under 40 CFR part 98 subpart RR or ends sequestration operations.
g. Acknowledgement of the geologic sequestration facility's duty to retain, for at least five years, all records required by the applicable provisions of the UIC program under 40 CFR part 146, subpart H, and the GHGRP pursuant to 40 CFR 98.3.
In addition to requiring a CCS plan at the time of registration, the EPA also proposes that the renewable fuel producer must provide a description of the CO
The proposed requirements associated with use of CCS as part of the RFS program would rely substantially, but not exclusively, on the requirements, processes, and methodologies established in the GHGRP and the UIC Program.
The sequestration facility injecting CO
Building on the foundation established by the UIC Program and GHGRP helps contribute to a consistent and transparent approach for facilities that use a renewable fuel production pathway involving CCS under the RFS program. At the same time, we are proposing several additional reporting and recordkeeping requirements in order to make sure the emissions reduction requirements of the RFS program are met. The EPA is proposing that producers of renewable fuel that achieve the GHG reductions necessary to qualify for a renewable fuel pathway by using CCS as part of the renewable fuel production process would have to calculate the lifecycle GHG emission value (LEV)
We are also proposing provisions in keeping with the reporting termination provisions of 40 CFR 98.441. These provisions establish that a facility reporting in accordance with the requirements of 40 CFR part 98, subpart RR, must continue to report, “until the Administrator has issued a final decision on an [injection well] owner or operator's request to discontinue reporting [under subpart RR].” Pursuant to 40 CFR 98.441(b), the facility may discontinue reporting under 40 CFR part 98, subpart RR by making a demonstration that current monitoring and model(s) show that the injected CO
The EPA is also proposing that, consistent with existing RFS requirements, all records associated with the use of CCS under the RFS program must be kept for five years to be consistent with other RFS program requirements.
One of the petitions the EPA received suggests an alternative crediting method relating to displacement of naturally occurring CO
The EPA is proposing that a renewable fuel producer using CCS to achieve the GHG reductions necessary to qualify for a given renewable fuel pathway can only generate RINs for a batch of renewable fuel if the lifecycle GHG emissions for the batch are determined to be below the threshold value for the applicable pathway by a method approved by the EPA as part of its response to a petition pursuant to 40 CFR 80.1416.
We are proposing that a renewable fuel producer using CCS to achieve the GHG reductions necessary to qualify for a given renewable fuel pathway could only generate RINs for a batch of renewable fuel if the calculated lifecycle GHG emissions for the batch are below the threshold value for the applicable pathway. In the context of using CCS as a lifecycle GHG emissions reduction technology in the RFS program, a calculation of lifecycle GHG emissions would consider whether CO
A key element of the proposed surface leak remediation process is the timely reporting of surface leaks by the renewable fuel producer to the EPA. Under 40 CFR part 98, subpart RR, of the GHGRP, the geologic sequestration facility is required to develop a strategy for detecting and quantifying surface leakage of CO
Under the proposed surface leak remediation process, the renewable fuel producer would need to submit a remediation plan to the EPA for approval within 30 days of notifying the EPA of the surface leak. The remediation plan would:
1. If possible, demonstrate that the PIRs are not invalid. For example, the producer could provide calculations showing that the surface leak did not result in lifecycle GHG emissions exceeding the GHG emission reduction threshold required for the renewable fuel production pathway for which RINs were previously generated and for future RINs that would be generated using the CCS pathway.
2. Describe corrective actions that:
a. When taken, would remediate the surface leak and that the renewable fuel producer working with the geologic sequestration facility was taking all necessary steps to ensure a high likelihood that no further CO
b. Demonstrate how the renewable fuel producer intends to take corrective action for any PIRs resulting from the surface leak. Corrective actions that could be part of a remediation plan could include retiring the PIRs or purchasing and retiring replacement RINs under 40 CFR 80.1474.
Again, we recognize that the 30-day period for renewable fuel producers to prepare and submit a remediation plan may appear to be a short time frame. However, we note that if the surface leak was immaterial (
Under the existing regulations, producers can already take corrective action under the options above. However, we are proposing that producers generating RINs under a CCS pathway would need to provide additional information to that already required under the PIR administration process (
Under this approach, the renewable fuel producer is responsible for submitting the remediation plan and ensuring that surface leaks are remediated at the geologic sequestration site prior to the further generation of RINs under a CCS pathway. We believe that continuing to have the renewable fuel producer ultimately responsible for all aspects related to the valid generation of RINs is consistent with our goals of promoting compliance within the RFS. However, we seek comment on this approach.
We are proposing that all RINs generated under a CCS pathway during the five years preceding the surface leak would be PIRs in the event of a surface leak at the facility sequestering CO
Under the proposed remediation process, failure to submit a remediation plan or take appropriate corrective action would trigger the procedures outlined in 40 CFR 80.1474 as discussed in the following paragraph. In addition, the EPA would only allow the renewable fuel producer to generate RINs using a CCS pathway after the EPA approves a remediation plan and the renewable fuel producer takes appropriate corrective action. If a renewable fuel producer does not notify the EPA of a surface leak within 24 hours of detection, stop RIN generation as described above, and comply with the PIR administrative procedures outlined in 40 CFR 80.1474, the renewable fuel producer would be deemed to have failed to have taken corrective action and all RINs generated under the CCS pathway during the five years preceding the leak could be considered invalid. However, the EPA is proposing that RINs generated under the CCS pathway prior to the five years preceding the leak would not potentially invalid.
The EPA believes that the proposed remediation process as a supplement to the existing PIR administrative process would allow renewable fuel producers an opportunity to remediate PIRs resulting from surface leaks without going through the process of replacing all RINs generated using a CCS pathway prior to the surface leak. The EPA recognizes that renewable fuel producers that generate RINs from a CCS pathway may not be able to replace RINs in the case of a large surface leak. Although we do not believe this is likely to occur, we seek comment on alternative corrective actions renewable fuel producers could take in order to remediate PIRs resulting from the surface leak. We also seek comment on the proposed remediation process and whether there is any additional information we should require of renewable fuel producers to ensure that PIRs resulting from surface leaks are appropriately addressed.
Through amendments to the CAA enacted as part of EISA, Congress established specific lifecycle GHG emission thresholds for each of four types of renewable fuels, requiring a percentage reduction compared to lifecycle GHG emissions for gasoline or diesel (whichever is being replaced by the renewable fuel) sold or distributed as transportation fuel in 2005. For example, the CAA requires a 50 percent reduction in order for a fuel to be classified as advanced biofuel.
Determining whether a fuel's lifecycle GHG emissions meet a threshold level of lifecycle GHG reduction requires a comprehensive evaluation of the lifecycle GHG emissions of the renewable fuel as compared to the lifecycle GHG emissions of the baseline gasoline or diesel fuel that it replaces. As mandated by CAA section 211(o), the lifecycle assessment must evaluate the aggregate quantity of GHG emissions (including direct emissions and significant indirect emissions such as significant emissions from land use changes) related to the full fuel lifecycle, including all stages of fuel and feedstock production, distribution, and use by the ultimate consumer.
As discussed above, the EPA proposes that at the time of registration, the renewable fuel producer must affirm that when using an EPA-approved approach, lifecycle GHG emissions associated with renewable fuel produced will be no greater than a specified threshold lifecycle emissions value. The lifecycle GHG calculation would be based in part on the amount of CO
The EPA is proposing to approve new fuel pathways for ethanol and naphtha produced from short-rotation hybrid poplar and willow using a production process that converts cellulosic biomass to fuel for the generation of cellulosic biofuel (D-code 3) RINs. We are also proposing to approve new fuel pathways for diesel, jet fuel, and heating oil produced from short-rotation hybrid poplar and willow using a production process that converts cellulosic biomass to fuel for the generation of cellulosic biomass-based diesel (D-code 7) RINs. As discussed in this section, the EPA's analysis shows that fuel produced from short-rotation hybrid poplar and willow using a variety of processing technologies meets the 60 percent GHG emissions reduction threshold needed to qualify as cellulosic biofuel. This section includes an overview of short-rotation hybrid poplar and willow growing systems, and explains our analysis of the lifecycle GHG emissions associated with these fuel pathways.
As part of the RFS2 final rule, the EPA analyzed various biofuel production pathways to determine whether fuels produced through those pathways meet minimum lifecycle GHG reduction thresholds specified in the CAA for different categories of biofuel (
The EPA requests public comment on our analysis of the lifecycle GHG emissions related to the production and use of biofuel from short-rotation hybrid poplar and willow. The EPA specifically requests comments on the modeling used to conduct our analysis, and the definitions of short-rotation hybrid
Short-rotation tree (SRT) systems, also known as short-rotation coppice (SRC), are stands of woody trees producing multiple stems from coppice growth, and harvested in relatively short rotations (generally less than 10 years) for bioenergy use. Common genera grown in SRT systems include
SRT systems can provide a number of environmental benefits over a tilled agricultural system. They result in greater accumulation of carbon through below-ground organic matter that goes undisturbed for longer periods of time, as well as protection against nutrient runoff and soil erosion due to larger root networks.
The EPA has analyzed a set of taxa being grown in short-rotation systems known as the hybrid poplar. Hybrid poplars are plants created by the cross pollination of multiple members of
The EPA also analyzed short-rotation willow, also known as shrub willow, which is another short-rotation species. Shrub willow refers to a number of
Willow also has a history as a bioenergy feedstock in numerous countries in Europe, including Sweden, the UK, and Poland, where it is pelletized and co-fired with coal in electricity generation to help meet renewable energy goals. By one estimate, there are over 40,000 acres of commercial plantings in Europe.
The EPA's analysis shows that fuel produced from short-rotation hybrid poplar and willow using a variety of processing technologies meets the 60 percent GHG emissions reduction threshold necessary to qualify as cellulosic biofuel. This section explains our analysis of the lifecycle GHG emissions associated with fuel produced from these feedstocks.
The EPA's analysis of the domestic impacts of short-rotation hybrid poplar and willow biofuel pathways use the same model of U.S. agricultural and forestry sectors that was used for the RFS2 final rule: The Forestry and Agricultural Sector Optimization Model (FASOM) developed by Texas A&M University.
For international impacts, we applied results from the switchgrass analysis performed for the RFS2 final rule. The switchgrass analysis used the Food and Agricultural Policy and Research Institute international model as maintained by the Center for Agricultural and Rural Development at Iowa State University (the FAPRI-CARD model). This approach is similar to the methodology we used to evaluate and approve other dedicated bioenergy feedstocks, such as energy cane, giant reed, and napier grass. As we discussed in the RFS2 final rule, some feedstock sources can be determined to be similar enough to those modeled that the modeled results could reasonably be extended to these similar feedstock types. Switchgrass, short-rotation hybrid poplar, and short-rotation willow are all dedicated bioenergy feedstocks, and are expected to grow on the same types of land and cause the same types of crop displacement. As the EPA assumed for the analysis of energy cane, giant reed, and napier grass, we do not believe that these bioenergy feedstocks will cause large land use change impacts, as they do not generate the economic returns of row crops on productive lands, and are therefore being targeted for development on less productive lands. For analysis of short-rotation hybrid poplar and willow, we scaled the switchgrass international emissions for yield differences in switchgrass, short-rotation hybrid poplar, and short-rotation willow, and applied these adjusted emissions to short-rotation hybrid poplar and willow.
To assess the impacts of an increase in renewable fuel volume from a “business-as-usual” scenario likely to have occurred without the short-rotation hybrid poplar and willow-based biofuels, we compared impacts in a control case to the impacts in two new cases: “short-rotation hybrid poplar biofuel” and “short-rotation willow biofuel.”
The scenario volume of 400 million gallons of biofuel per year used in the model is the target production level of hybrid poplar based biofuel as of 2012 by Advanced Hardwood Biofuels Northwest (AHB), a USDA-funded consortium of universities and industry partners. We believe this is a reasonable volume to model for a number of reasons. While there is little production of short-rotation hybrid poplar or willow-based biofuel currently, the biotechnology company Zeachem Inc., with a loan guarantee from USDA, is planning a 25 million gallon/year cellulosic biorefinery in Boardman, Oregon, sourcing hybrid poplar as the primary feedstock. Zeachem Inc. currently operates a 250,000 gallon/year demonstration plant also in Boardman, Oregon. Although these currently identified projects are much lower than the 400 million gallons modeled, there is also data supporting larger volumes. For example, the Department of Energy (DOE), in the 2011 “U.S. Billion Ton Study Update” assessed the potential supplies of bioenergy feedstocks at various economic conditions. At baseline conditions, they concluded that in 2022, 67 million dry tons of “woody crops” (roughly 6 billion gallons of biofuel) could be supplied at $50/dry ton.
Understanding the uncertainty in the ability for hybrid poplar and willow biofuel to penetrate and grow in the market, we also analyzed smaller volume scenarios as a sensitivity analysis that is included in the memo to the docket. The purpose of doing so was to test the GHG emissions impact of a lesser demand for these fuels on agricultural markets and land use. These lower volume scenarios produced agricultural market and land use impacts on a per-gallon basis that were similar to the respective 400 million gallon/year scenarios, and LCA GHG results were also consistent with the larger volume scenarios.
Similar to our analysis of renewable fuel feedstocks in the RFS2 final rule, the EPA assessed what the lifecycle GHG emissions impacts would be from the use of additional volumes of short-rotation hybrid poplar or willow for biofuel production. The information provided below discusses the outputs of the analysis using the FASOM model to determine changes in the domestic agricultural and livestock markets. We then discuss the results of our analysis of international impacts from the switchgrass analysis in the RFS2 final rule. Finally, we discuss other GHG emissions associated with the pathways, and conclude with a summary of all GHG emissions associated with the production of biofuel from short-rotation hybrid poplar or willow feedstock.
Using FASOM, we estimated the domestic impacts of producing 400 million gallons of biofuel from short-rotation hybrid poplar or willow. FASOM estimates that 6.3 million tons of additional short-rotation hybrid poplar production will be needed to produce 400 million gallons of ethanol in 2022, and that these tons will come exclusively from around 950,000 acres in the Pacific Northwest East region of FASOM. The Pacific Northwest East region, which covers Oregon and Washington, east of the Cascade mountain range, has the highest yield in the model. The Pacific Northwest East region is also the location of actual current production. The increased short-rotation hybrid poplar production in the Pacific Northwest East causes cropland in this region to be shifted away from wheat, barley, and hay. Although production of these crops increases in other regions, overall the national production of these crops decreases (see Table VI.C.2-1).
The total active cropland in the U.S. increases by 260,000 acres in 2022 (see Table VI.C.2-2). These additional acres primarily come from the conversion of idle cropland (131,000 acres), pastureland (72,000 acres), and forests (57,000 acres) to active cropland.
In the short-rotation willow scenario, approximately 6.5 million tons of short-rotation willow will be needed to produce 400 million gallons of ethanol in 2022. Like short-rotation hybrid poplar, short-rotation willow currently has no commercial market in FASOM, and all of the short-rotation willow for fuel comes from new production. In 2022, all short-rotation willow production is projected to be in the Northeast, and around 1.2 million acres will be required.
For this high-volume willow scenario, the total active cropland in the U.S. increases by 363,000 acres (see Table VI.C.2-2). The cropland comes primarily from the conversion of forest (212,000 acres), pastureland (90,000 acres), and idle cropland (60,000 acres) to active cropland.
As explained above, the results of the FASOM model provide insights into the domestic impacts of producing biofuel from short-rotation hybrid poplar or willow. In this section we explain the international impacts. The FASOM model shows that in the short-rotation hybrid poplar and willow scenarios, the national production of crops such as wheat, corn, and soybeans will decrease as a result of increased land competition.
GHG emissions associated with distributing short-rotation hybrid poplar and willow are expected to be similar to the EPA's estimate for switchgrass because they are all dedicated bioenergy feedstocks requiring similar transport, loading, unloading, and storage regimes and have similar conversion yields as discussed in section VI.C.5 of this preamble. Our analysis therefore assumes the same GHG impact for feedstock distribution as we assumed for switchgrass.
Short-rotation hybrid poplar and willow are suitable for the same conversion processes as other cellulosic feedstocks, such as switchgrass and corn stover. Currently available information on short-rotation hybrid poplar and willow composition shows that their hemicellulose, cellulose, and lignin content are comparable to or higher than other feedstocks that qualify under the RFS regulations for the production of cellulosic biofuels. Conversion yield data provided by a technical assessment of cellulosic feedstocks by National Renewable Energy Laboratory (NREL) suggests that the yield will be higher for short-rotation hybrid poplar and willow than for other cellulosic feedstocks.
As described above, we analyzed the GHG emissions associated with agriculture, land use change, fuel and feedstock transport, and tailpipe emissions for renewable fuels produced from short-rotation hybrid poplar and willow. Tables VI.C.6-1 and VI.C.6-2 break down by stage the lifecycle GHG emissions of the 2005 gasoline and diesel baselines and of short-rotation hybrid poplar and willow fuels produced in 2022.
Net agricultural emissions include domestic and international impacts related to changes in crop inputs such as fertilizer, energy used in agriculture, livestock production, and other agricultural changes in the scenarios modeled. Increased demand for short-rotation hybrid poplar or short-rotation willow results in negative net agricultural emissions, meaning the emissions decrease relative to the control case. Short-rotation hybrid poplar and short-rotation willow use fewer agricultural inputs than corn, soybeans, barley, and wheat. Because land was converted from these crops to short-rotation hybrid poplar or short-rotation willow production, there was a reduction in the usage of agricultural inputs, and a corresponding reduction in the emissions from farm inputs.
Domestic land use change emissions are negative for short-rotation hybrid poplar and willow. One reason for this is that most of the land used for short-rotation hybrid poplar or willow production comes from existing cropland. Using this cropland for short-rotation hybrid poplar or willow rather than annual crops like corn or wheat increases the amount of carbon stored in the soil and below-ground biomass (roots) due to the longer rotation and no-tillage characteristics of short-rotation hybrid poplar and willow. Another reason for the decrease in domestic land use change emissions in 2022 is due to more intensive management of forest acres in response to expected pressure on forest acres and forest product supply in the future.
As a result of increased demand for short-rotation willow and hybrid poplar, international land use change emissions increase. The increase in international land use change emissions for short-rotation hybrid poplar and short-rotation willow are larger than the decrease in domestic land use change emissions, leading to a net increase in land use change emissions.
The fuel production stage includes emissions from ethanol or diesel production plants, as described in section VI.C.5 of this preamble. Fuel and feedstock transport includes emissions from transporting short-rotation hybrid poplar or willow from the farm to a fuel production facility. As we assume for cellulosic pathways approved under the 2010 RFS2 final rule for the biochemical conversion process, lignin from the feedstock is burned to produce electricity, which offsets grid electricity, resulting in negative emissions. Even without this credit, short-rotation willow and hybrid poplar would meet the 60 percent GHG reduction threshold.
For short-rotation hybrid poplar, total emissions are 77-132 percent lower than the 2005 gasoline or diesel baseline. For short-rotation willow, total emissions are 69-125 percent below the gasoline or diesel baseline. These results, if finalized, would justify a determination that short-rotation hybrid poplar and willow ethanol, diesel, jet fuel, heating oil, and naphtha would meet the 60 percent reduction threshold required to qualify as cellulosic biofuel.
Although this analysis assumes short-rotation hybrid poplar and willow biofuels produced for sale and use in the U.S. will most likely come from domestically produced feedstock, we also intend for the proposed pathways to cover short-rotation hybrid poplar and willow from other countries. We do not expect biofuels from short-rotation hybrid poplar and willow feedstocks produced in other nations to have significantly different lifecycle GHG emissions than we have calculated for domestically-produced fuels. As explained above, we believe that increased transport for fuel produced internationally would only increase the total lifecycle GHG emissions by at most 1-2 percent. Moreover, other countries most likely to be exporting short-rotation hybrid poplar, short-rotation willow, or biofuels produced from these feedstocks are likely to be major producers that typically use similar cultivars and farming techniques. Therefore, GHG emissions from producing biofuels with short-rotation hybrid poplar and willow grown in other countries should be similar to the GHG emissions we estimated for U.S. short-rotation hybrid poplar and willow, though they could be slightly (and insignificantly) higher or lower.
Poplars (
As discussed previously, the EPA's analysis shows that fuel produced from short-rotation hybrid poplar and willow using a variety of processing technologies meets the 60 percent GHG emissions reduction threshold needed to qualify as a cellulosic biofuel. Therefore, we are proposing to modify rows K, L, and N of Table 1 to 40 CFR 80.1426 to add these new pathways. Producers would then be able to submit registration materials to produce renewable fuels through these pathways, subject to compliance with all applicable regulations. We invite comment on all aspects of this analysis.
For purposes of the RFS program, we are proposing that short-rotation hybrid poplar means a species or cross of species in the
To be used as feedstock for qualifying renewable fuel under the RFS program, short-rotation hybrid poplar and short-rotation willow must be grown on a tree plantation as defined in 80 CFR 1401, and producers of fuel made from such feedstock must meet all of the registration, recordkeeping, and reporting requirements specified in the regulations for producers of renewable fuel made from qualified planted trees or tree residues. These requirements are designed to implement the statutory requirement that qualifying renewable fuel be made from “renewable biomass” as defined in the CAA, including “planted trees and tree residue from actively managed tree plantations on non-federal lands [. . .].” Among other requirements, the current regulations specify that a tree plantation must have been actively managed as a tree plantation on December 19, 2007, and that producers using these feedstocks maintain records serving as evidence that this is the case. However, we believe that the central purpose of the renewable biomass requirement is to prevent the conversion of land that was not cleared and actively managed as agricultural land as of the date of EISA enactment from being converted to production of renewable fuel feedstocks. This purpose can be satisfied with respect to tree plantations providing the land in question was cleared and
The EPA is proposing new registration and recordkeeping requirements for renewable fuel producers generating cellulosic biofuel (D-code 3) or cellulosic biomass-based diesel (D-code 7) RINs for renewable fuel produced from short-rotation hybrid poplar or willow. These requirements are to ensure that feedstocks used for these pathways meet the definitions of short-rotation hybrid poplar or willow and that the feedstocks were grown on tree plantations as defined in 80.1401. At registration, producers would be required to list all species and hybrids that they intend to use as a short-rotation hybrid poplar or willow. In addition, they would need to provide a written justification of why each feedstock meets the definition of short-rotation willow or short-rotation hybrid poplar, including the specification that the harvest rotation is less than 10 years. Finally, at registration the producer would have to submit records (including contracts and affidavits from the tree plantation supplying the feedstocks) demonstrating that the short-rotation hybrid poplar or short-rotation willow feedstocks will be sourced from a tree plantation, as defined in 40 CFR 80.1401.
The EPA is proposing additional recordkeeping requirements for renewable fuel producers using short-rotation hybrid poplar and short-rotation willow. Producers would be required to keep records of the specific short-rotation hybrid poplar or willow species or hybrids used to produce renewable fuel for each batch of fuel produced, the total quantity of each feedstock used for each batch, and the total amount of fuel produced in each batch. In addition, producers would be required to keep affidavits obtained on a quarterly basis and contracts from the short-rotation hybrid poplar or short-rotation willow feedstock providers confirming that the feedstocks provided are from a tree plantation meeting the definition in 80.1401. We invite comment on the proposed new registration and recordkeeping requirements for short-rotation hybrid poplar and short-rotation willow.
In addition to these new proposed requirements, renewable fuel producers using short-rotation hybrid poplar and short-rotation willow would need to comply with all existing applicable regulatory requirements. Short-rotation hybrid poplar and willow are considered planted trees as defined in 40 CFR 80.1401. Applicable requirements include but are not limited to registration requirements at 40 CFR 80.1450(b)(1)(ii), which require producers to demonstrate that their production process has the ability to convert cellulosic components of their feedstock into fuel. Producers using short-rotation hybrid poplar and willow as feedstocks would also have to comply with all applicable reporting requirements and submit quarterly reports pursuant to 40 CFR 80.1451(d). Producers would also have to report the specific type and quantity of each short-rotation hybrid poplar or willow species or hybrids used as feedstocks to produce the renewable fuel in EMTS consistent with existing requirements for all renewable fuels.
The RFS regulations currently contain pathways for the generation of cellulosic RINs when electricity, produced from biogas, is used as a transportation fuel.
The EPA has received a number of registration requests for approval under the existing provisions for generating RINs for renewable electricity generated from biogas.
Given the diversity of the registration requests submitted for the generation of RINs for renewable electricity to date, and the necessity of avoiding the double-counting of RINs for the same quantity of electricity, the approval of any one of these proposed systems may preclude the approval of others. The regulations prohibit double-counting of RINs for the same quantity of renewable electricity. Thus, for a given quantity of renewable electricity, at most one party—whether it is the electricity producer, the utility distributing the electricity, the EV owner, the charging station, or the manufacturer—can generate the corresponding RINs. The EPA believes the question of the appropriate party to generate RINs in these circumstances deserves the opportunity for public comment. In determining the regulatory requirement for parties seeking to generate RINs for renewable electricity, our goal is to establish an open and comprehensive program that will best incentivize growth in the use of renewable electricity without sacrificing the integrity of the RIN market. We seek comment on the following discussion and potential RIN generation structures for renewable electricity in order to help resolve the many issues associated with choosing an appropriate structure and its design, as well as which of these structures would best further the goals of the RFS program. Feedback received in response to this request for comment will be essential to ensuring that an equitable, open, and comprehensive program structure is adopted and implemented.
A key requirement of the RFS program is the type of data required to demonstrate that RINs were generated validly and identification of who is responsible for providing the necessary data for RIN generation. Vehicle charging data demonstrate the use of electricity as transportation fuel, one of the two main requirements for RIN generation (production from renewable biomass being the other). However, there are several sources of charging data that could be provided to verify the use of electricity as transportation fuel:
Any of these sources of data could conceivably be used as the basis for generating RINs for renewable electricity.
Although multiple types of data can be used to demonstrate the use of electricity as transportation fuel, allowing them to be used simultaneously would almost certainly result in the generation of RINs by multiple parties for the same charging event (
In addition to determining the type of information that will be required for RIN generation for renewable electricity, the EPA proposes to determine the extent to which parties authorized to generate RINs would be allowed to use estimates or averages (rather than empirical data) for the basis of RIN generation. These estimates or averages could range from relatively simplistic (
• Allow utilities or other parties to estimate the quantity of electricity used as transportation fuel by all EVs within their customer base.
• Allow a hybrid system wherein different types of parties (
Whether it is necessary for the EPA to adopt a system that strictly requires empirical charging data, rather than a system that allows for reasonable assumptions, remains undecided. The empirical data approach would require that large quantities of data be generated, managed, and provided by the RIN generator. A program of that scope could be resource intensive for both the RIN generator and the EPA and, depending on the approach, may prevent large-scale participation, thereby undermining the potential of the RFS program to stimulate EV usage, infrastructure, and reduce GHGs.
A program that relies upon some degree of simplification, through assumptions, would reduce resource allocation for data generation and oversight. This reduced complexity may allow for a larger variety of parties to participate in the RFS program and would likely increase participation, the number of RINs generated, and encourage future growth. Allowing the use of assumptions, such as estimates or averages, would sacrifice some of the precision present in systems that rely on empirical data, but it may also help mitigate concerns over data ownership and consumer privacy infringement. For example, if the quantity of RINs that could be generated annually by an EV were determined based upon average vehicle miles traveled, rather than empirical charging data, knowing the size of the fleet for a given year is all that is required rather than vehicle-specific charging data. There are privacy and data ownership concerns that may arise with any structure that requires empirical charging data from the EV. Issues surrounding data ownership and privacy concerns are present throughout the structures described below. Some of these structures offer more established pathways to resolution (
Another important consideration for the EPA in determining the data requirements to allow for RIN generation for renewable electricity is
Allowing the generation of RINs for renewable electricity under the RFS program provides a potentially significant opportunity to incentivize investment in EV technologies and infrastructure, as well as the generation of electricity from biogas. However, the unique characteristics of the generation and tracking of renewable electricity from biogas present implementation challenges. The EPA is aware that how these challenges are dealt with and resolved will have significant consequences for who can generate RINs for renewable electricity, how the program is implemented and monitored, the level of program participation, and the degree to which RINs will be used to incentivize growth in the number of EVs, the charging infrastructure, and the generation of electricity from biogas for use as transportation fuel.
In light of these concerns, the EPA is seeking comment on the type of structure and accompanying data to be employed in allowing parties to generate RINs for renewable electricity. The following sections discuss several potential structures considered by the EPA and informed by preliminary discussions with several stakeholders. Each of these structures addresses the two primary RFS requirements for the generation of RINs for renewable electricity: (a) That renewable electricity has been generated from approved renewable biomass (biogas); and (b) That the renewable electricity is used as transportation fuel. Some of the structures discussed below are better positioned to verify the first requirement (the generation of electricity from biogas), while others are better positioned to verify the latter requirement (that electricity is used as transportation fuel). All of these structures are being considered on an individual basis, but could also be considered in the context of a hybrid approach that would combine multiple structures and/or reserve percentages of the RINs from renewable electricity for specific structures (
Any of the structures (or hybrids thereof) would impose significant, additional implementation challenges. The current RFS program would need to be adjusted to accommodate new registered parties (
The EPA believes that the best-case scenario would be the adoption of a structure for generating RINs for renewable electricity that would simultaneously provide greater incentive for EV use and ownership (thereby reducing air pollution and GHG emissions from vehicles), increase the amount of renewable electricity produced, and minimize challenges related to program oversight. As of 2014, however, roughly 11,000 GWh of electricity were generated from biogas, while slightly less than 700 GWh from all sources were used as transportation fuel. This means that in the near term, the number of RINs that are able to be generated from renewable electricity will likely be limited by the size of the EV fleet. Structures that do not incentivize increased ownership of EVs are therefore likely to have limited impact on the quantity of renewable electricity produced in the near term. Any program that does not induce additional electricity generation from biogas is not expected to provide additional GHG reductions beyond those provided by the efficiency of the additional EVs added to the fleet. Finally, in order to fully understand the implication of our decision on the structure for the generation of RINs for renewable electricity, we believe we should take into account the existing and significant incentives currently in place for the production of EVs and the generation of electricity from biogas.
We understand that many of the options under consideration differ from the typical approach under the RFS of placing authority and responsibility for RIN generation on the renewable fuel producer. We believe that a unique approach with respect to renewable electricity could be justifiable if it provides greater incentives for use of renewable electricity in the transportation sector and simplifies program implementation, but we seek comment on this issue.
One possible program structure would be to allow vehicle owners to use the data on the quantity of electricity used to charge their EVs, as measured by separate meters or telemetric devices, to generate RINs. Under this system, the data available to the RIN generator clearly demonstrate the use of electricity as transportation fuel. Allowing EV owners to generate RINs for renewable electricity could provide a direct financial incentive to owners and potential owners of EVs; however, such a system would have several major challenges that the EPA believes would prevent this structure from achieving the desired impact.
One major issue for EV owners is to measure and keep records of the amount of electricity used to charge their EVs. Barriers currently exist for vehicle owners to access and log their vehicle charging activity. Vehicle owners may opt for a second electricity meter to be installed by their utility company, which would then provide charging activity information through a dedicated billing account. The validity of charging data captured by dedicated EV charging meters would be verifiable and documented. Alternatively, vehicle owners may opt to purchase a current measurement device capable of measuring and logging charging activity.
The extent of verification challenges related to charging data captured through an independent current management device is unclear is unclear and we request comment on this issue. Either of these options would necessitate an initial financial investment, which could reduce program participation.
Even if EV owners were able to log their vehicle charging activity through one of these options, there would still be a challenge for program administration because the EPA would need to collect and verify the accounting accuracy of the charging data compared to number of RINs generated for each individual EV owner (
A second major issue would be the need to verify that the vehicle charging was completed using electricity generated from renewable biomass. Individual vehicle owners would likely be unable to enter into direct contracts with independent power producers or investor-owned utilities in order to demonstrate the renewable content requirements for RIN generation. Broad EV owner participation would therefore likely necessitate the creation and maintenance of a novel contract mechanism by the EPA or the involvement of a third-party aggregator in order to fulfill the requirements for RIN generation. A substantial degree of simplification for assuring renewable content, as well as eliminating charging data measurement and reporting by vehicle owners, could be achieved through the use of assumptions. The complexity of administering the vehicle owner structure could be greatly reduced by modeling usage behavior and then allowing a third party to aggregate vehicle owners and contract to meet renewable content requirements. The third party could then distribute RIN value to vehicle owners, less administrative costs, after the sale of RINs to obligated parties. Some mechanism for aggregation would be required, as another major issue is the sale of small numbers of RINs. Under the RFS program, obligated parties purchase RINs in blocks of millions and are not set up to purchase small numbers from individual parties. Therefore, aggregation would almost certainly be a necessity for the vehicle owner structure or any other structure predicated upon the generation of small numbers of RINs by a single party.
It is conceivable that owners of large EV fleets may be willing to meet the administrative and recordkeeping challenges posed by RIN generation under a non-assumption based version of the vehicle owner structure. However, because the number of EVs in fleets is small relative to the total number of EVs in the market, allowing for this structure alone would not maximize the number of RINs generated. Under a strictly empirical data version of the vehicle owner structure, even EV owners willing and able to create and maintain the necessary records would likely be dependent on a third-party aggregator to generate and sell RINs on their behalf, as the registration requirements and realities of the RIN market
Another potential structure could allow the owners of vehicle charging stations to generate RINs based on the electricity used by their charging stations. Charging data from public stations could be verified by meter billing statements that would be readily available to participating stations. Allowing charging station owners to generate RINs could also incentivize the building of additional public charging infrastructure, which could also impact the willingness of consumers to purchase and use EVs. If this structure were adopted, it is probable that the EPA could rely on verifiable empirical charging data (rather than estimates or averages) for the amount of renewable electricity used. However, such charging stations would still have to contract with upstream parties to verify that the renewable electricity used as transportation fuel for which RINs were generated was consistent with the quantity of renewable electricity generated from qualifying renewable biomass supplied to the grid from which the charging stations withdrew their electricity.
The program administration challenges for the EPA under this structure would be to verify and rectify contracts among all of the parties upstream of the charging station, particularly when there are multiple parties involved. For example, it is particularly challenging for the EPA to ensure that RINs are generated only for the quantity of electricity that is actually produced at a renewable electricity generation facility if the facility has multiple contracts with multiple charging stations for a portion of their electricity. The charging station would not know if they were contracted for a quantity of electricity that was above the capacity of the renewable electricity generation facility, and therefore the burden would fall on the EPA, or others, to conduct this verification. We seek comment on how to overcome this implementation challenge without imposing overly burdensome restrictions on how parties set up contracts and conduct business in this competitive market.
Additionally, a majority of EV charging is currently performed at work or home. Therefore, adopting this structure alone would limit the ability to achieve the desired goals of the RFS program. Even if all public charging station owners were able to participate in the RFS program, this structure would not allow for the generation of RINs for renewable electricity when EVs are not charged at public charging stations. This would significantly limit the number of RINs that could be generated for renewable electricity, thereby reducing the effectiveness of this structure to be used to incentivize ongoing EV growth. It is possible that this structure could be used in
Another challenge of this structure is that many of the public charging stations are owned by municipalities or other entities that may find it difficult, due to human resource or other constraints, to make their charging data available and participate in the RFS program. These challenges, though unique to charging stations, are not materially different than the challenges that were outlined in the vehicle owner structure for smaller entities generating RINs and participating in the RFS program. Whether adopted alone, or in concert with another structure to capture home charging, the difficulties associate with recordkeeping, reporting, and the likely need to aggregate small RIN generators so that they may participate in the RIN market are present and will need solutions prior to the public charging structure being ready for implementation.
While the other structures discussed here allow one to more easily quantify and verify the amount of electricity used as transportation fuel, they are far removed from the point where one can verify that the feedstock used to generate the renewable electricity was actually qualifying renewable biomass (
There are several additional reasons beyond the physical connection to the qualified biomass being converted to electricity as to why an electric utility structure may be desirable. Depending on the design of the program, value from RINs generated by utilities could incentivize new forms of biomass to electricity generation or drive the increased use of biogas to generate renewable electricity, providing GHG benefits. It could also provide a source of revenue for utilities to help offset the cost of upgrading electricity distribution infrastructure, which would likely be necessary if EVs are adopted to a significant degree. Finally, as the parties that sell electricity to the end users, utilities would conceptually be best positioned to provide renewable electricity to EV owners at discounted rates.
A version of this form of structure has been adopted by the State of California in their Low Carbon Fuel Standard Program (LCFS). Under the LCFS, electric utilities generate credits based upon the number of EVs in their service territories. The amount of electricity used by each vehicle is estimated based on data from a limited number of EV owners with separate meters to directly measure the amount of electricity used to charge their vehicles. The LCFS program also allows public charging stations and fleet owners to generate credits based on charging data. The system addresses the potential for generating multiple credits for the same charging event by allowing utilities to generate credits based on estimates of the electricity used only for the home charging of EVs, while allowing public charging stations and fleet owners to generate credits based on their own charging data.
Unlike the RFS program, the LCFS program has no requirement that the electricity used to generate the LCFS credits come from any specific source. Their program relies on a grid average carbon intensity to determine the amount of LCFS credits that are to be awarded for each charging event. This is fundamentally different from the requirements under the RFS program, where credits may only be generated for electricity generated from qualifying renewable biomass sources.
The use of grid average carbon intensity also obscures another important issue which will need to be resolved by any national structure for RINs generated for renewable electricity: Most facilities generating electricity from biogas are independent power producers (IPPs) not owned by electric utility companies. In 1978, the Public Utility Regulatory Policy Act (PURPA) was passed, granting qualifying facilities the right to be able to generate and sell electricity to utility companies at the utility's avoided cost.
This disaggregation introduces a potential challenge to the electric utility structure. Any utility-based structure would likely need to determine whether to allow utilities to contract with IPPs currently generating electricity from biogas or require that the utilities directly generate electricity from biogas in order to generate RINs for renewable electricity. Allowing utilities to contract with IPPs would likely result in the greatest participation in the RFS program, but may limit the procurement of new biogas generation in the near term (until the amount of electricity used as transportation fuel nears the amount of electricity presently generated from biogas). Alternatively, requiring that utilities generate the RINs for biogas generation capacity they either already own or newly procure could provide an incentive for increasing the amount of electricity generated from biogas, but would likely reduce utilities' participation in the RFS program.
In summary, the utility centric structure has some advantages, such as most directly providing the linkage to the renewable nature of the RINs generated, and could provide funds for the upgrading of electricity distribution infrastructure. In addition, the utility structure could be used in conjunction with the public charging structure used to separately capture private and public charging of EVs. There remain several challenges to the adoption of the utility centric structure however. The disaggregated nature of electricity generation from biogas would provide program administration challenges. A decision about whether or not to allow utilities to contract with IPPs to fulfill the requirement that the renewable electricity was generated from biogas would have to be made. Finally, questions remain as to the degree to which utilities, many of which are publicly regulated entities, would be legally able to participate in the RFS program as RIN generators, or whether they would be dependent on third parties to generate RINs on their behalf. We request comment from such entities regarding potential legal issues that may limit or prevent their participation.
An additional RIN generation structure option would be a program that would use charging data collected by the vehicle manufacturer as the basis for RIN generation. This structure, like the vehicle owner and public charging station structures, is focused on quantifying the amount of electricity used as transportation fuel and less well-suited to ensuring that the electricity is generated from qualifying renewable biomass pursuant to an approved pathway (
The vehicle manufacturer structure, due to the ability of OEMs to independently generate charging data, could be adopted unilaterally or this structure could be used in conjunction with another structure (
From a program administration perspective, the parties that would be able to generate RINs for renewable electricity in a vehicle manufacturer structure would be a small pool of relatively homogenous applicants. It has been suggested that vehicle manufacturer telematics data could be used, in a raw or processed form, as the basis for RIN generation. However, EMTS is not currently configured to accept, process, or track the quantity and format of information that may be provided from vehicle telematics. Although these data could perhaps provide reliable information for RIN generation, the parsing of the substantial amount of information down to the vehicle level would be difficult to review for RIN verification. Significant modifications to EMTS and the registration system would still be needed to allow for the appropriate generation and tracking of RINs using data from EV manufacturers at this time.
Another aspect of the vehicle manufacturer centric structure is that it could also be administered to allow for the use of assumptions or models rather
Like the utility centric structure, the vehicle manufacturer centric structure does not preclude a hybrid option where public or private charging stations could also be RIN generators. In order to avoid the double-counting of RINs, many different approaches could be adopted. A simplistic hybrid approach would be to adopt a market segmentation similar to that employed by California in the LCFS. Under this structure a certain percentage of the market, based on the percentage of EV charging that is expected to take place at public charging stations, is reserved for public charging stations. The number of RINs that vehicle manufacturers would be able to generate would be reduced by a corresponding percentage which could vary depending on the extent to which vehicles produced by a particular manufacturer are designed to use public charging stations. The intent of this reduction would be for vehicle manufacturers to capture only the charging of EVs that happens at the vehicle owner's homes. This approach is coarse in the sense that discounting the total RINs which were measured (or modeled) by the vehicle manufacturers by a percentage and then allowing charging stations to generate RINs based upon their aggregated charging data could result in more or less RINs being awarded than should have been depending upon the actual home to public charging split. However, this approach would simplify implementation and allow a hybrid system to incentivize both EVs and charging infrastructure.
In summary, the vehicle manufacturer centric structure has several potential advantages (potential for simplicity of implementation and providing financial incentives to increase the adoption rate of EVs), as well as some issues which would need to be resolved. Vehicle manufacturers have a privileged position in terms of access to charging data, and would thereby have the least amount of need to create complex registration requests. Vehicle manufacturers also have an opportunity to resolve potentially complex data ownership issues surrounding EV charging data. There is also flexibility in this program structure for the use of assumptions and models that could serve to reduce administrative and applicant resource expenditure, which could lead to greater program participation. Vehicle manufacturers, however, would have to rely on contractual mechanisms to verify that the electricity used as the basis for RIN generation was generated from qualifying biogas and that the electricity was introduced into a grid servicing their customers. A single vehicle manufacturer would likely need to rely on a sizable number of contracts with IPPs, given the small scale of many IPPs that generate electricity from biogas and the necessity for the IPPs to be able to supply electricity onto the electrical grid from which the manufacturer's EVs draw electricity.
The EPA has received input from various parties regarding the equivalence value assigned to RINs generated for renewable electricity used as transportation fuel. A number of these parties have voiced concern that the unique nature of electric vehicles warrants an equivalence value calculated using a different set of parameters than those used to calculate the equivalence value of other renewable fuels under the RFS program. The EPA acknowledges that there are undoubtedly differences between vehicles that use internal combustion engines (ICEs) for propulsion and those that utilize electric motors. Whether the equivalence value for RINs generated for renewable electricity should be evaluated differently in light of these differences is a considerably more complex issue, and as such, the EPA would like to open up the issue of the renewable electricity RIN equivalence value for public comment. We are not at this time seeking comment on the how equivalence value is calculated for fuels other than renewable electricity.
The history of how equivalence values were conceived and calculated plays an important role in how the discussion on potentially establishing a unique equivalence value for RINs generated for renewable electricity should be framed. In the preamble to RFS1 final rule we stated:
This language establishes two important precepts: (1) Equivalence values are to be calculated using both the renewable content of the fuel and its energy content; and (2) Corn-based ethanol was selected as the reference fuel. These principles were reaffirmed in the current regulatory structure for the RFS program in 2010 when the EPA decided, through a notice and comment rulemaking, to retain the use of an energy and renewable content-based equivalence value for purposes of calculating the number of RINs generated for any quantity of renewable fuel. Therefore, the EPA has maintained the position that although there are efficiency differences present in the operation of ICEs, including those powered by different fuels, the current equivalence value of 22.6 kWh per gallon of ethanol is appropriate. However, due to concerns raised by various parties that maintaining this position may unduly negatively affect the renewable electricity pathway, we are seeking comment on whether a
Proponents of revising the equivalence value for renewable electricity have noted that aside from electricity, all of the approved fuels under the RFS are chemical fuels and this difference requires a novel approach. Their supporting reasoning is as follows: Electric motors used to propel a vehicle are not subject to the same fundamental efficiency limitations of ICEs. This makes electricity fundamentally different and unique and means that a “gallon of gasoline equivalent” of electricity in the battery of an EV provides several times more miles of transportation service than a gasoline vehicle with a gallon of ethanol in the tank. If we constrain the bounds of the analysis to a “tank-to-wheels” efficiency metric as they are suggesting should be done, then it is undeniable that EVs are far more efficient that ICE powered vehicles. A representative value for a tank-to-wheels efficiency for EVs is near 90 percent, whereas a value around 20-30 percent is representative of ICEs. Using this logic, it is understandable that proponents of revising the equivalence value feel that the EPA is not capturing the superiority of EVs consuming renewable electricity compared to ICEs consuming chemical fuels in the current equivalence value. However, it should be noted that the EPA is currently giving credit for electric vehicle efficiency to vehicle manufacturers under the Light Duty Vehicle GHG program.
An alternative interpretation could also be reached if the scope of the analysis is broadened. Using a source of renewable electricity, landfill gas (LFG), as the starting point of this comparison, there are currently two approved pathways under the RFS program by which LFG can be utilized to generate RINs. One of these is the direct use of the cleaned LFG to generate renewable electricity (referred to as “Electric”), typically in an ICE or a turbine. The other pathway is to upgrade the LFG to high BTU “Renewable Gas” (referred to as “Gas”), which can then be compressed and used in CNG/LNG vehicles as transportation fuel. As shown in Figure VII.D.1-1 below, these two pathways are assessed to determine the quantity of original energy content from the LFG that is ultimately available to provide drive energy to propel a vehicle. Starting with a nominal unit of energy, each conversion process in the value chain for each respective pathway is assessed a high and low efficiency to provide a rough bandwidth for drive energy efficiency.
The specific assumptions for this illustrative comparison for the efficiency of the energy conversion processes in Figure VII.D.1-1 are presented in Table VII.D.1-1 below.
The energy required for gas compression for the gas pathway was calculated assuming an isentropic efficiency of 80 percent, a CNG pressure of 3600 psi, and it was assumed that the compressor was consuming electricity generated from LFG at an efficiency of 35 percent. This way of representing the energy penalty of upgrading LFG to CNG may be simplistic, but we believe it provides sufficient accuracy for this relative assessment of the two pathways. The “tank” to wheels efficiency values for ICE engines
The key point illustrated by the Figure VII.D.1-1 is that the Electric pathway is not always superior to the Gas pathway on a drive energy provided basis when starting with the same quantity of landfill gas. Depending on the efficiencies for key energy conversion processes, either of the pathways can appear superior to the other. By contrast, an analysis using median efficiency values for all the energy conversion processes highlighted, would find that the overall efficiency of converting LFG to drive energy in a vehicle is roughly equivalent regardless of the pathway chosen. If both pathways generated RINs based upon the quantity of LFG used, the resulting interpretation of delivered drive energy parity between the pathways for establishing a novel equivalence value for the electricity pathway would likely be that no change to the EPA's current energy content methodology would be warranted. However, neither pathway is currently evaluated based upon the quantity of LFG used to deliver drive energy.
Another important, and tightly coupled aspect, of the equivalence value issue is where the RINs are generated along the value chain. Whether bulk gas from the LFG producer, electricity generator LFG consumption or electricity production, electrical feed to the battery charging device, or onboard vehicle state of charge is designated as the point of RIN generation can have a significant effect on the quantity of RINs generated. The determination of an appropriate point in the value chain for RIN generation is a major factor highlighted by parties suggesting an undervaluation of RINs generated from electricity. Those stakeholders have asserted that there is inequity created by allowing the Gas pathway for LFG to be measured on the upstream side of the ICE (the vehicle's ICE) while the Electric pathway is required to be measured on the downstream side of the ICE (the electrical generation equipment). This idea is illustrated in Figure VII.D.2-1 below, where each LFG pathway starts with 1 MMBTU of cleaned LFG on the left and the required conversion processes for each pathway are applied cumulatively moving to the right.
The quantity of energy from the nominal cleaned LFG that remains for Vehicle Drive Energy is very similar for each pathway. However, due to the point in the process at which energy is measured for RIN generation in the two pathways currently, the Gas pathway produces roughly 3.5 times the RINs for an equivalent quantity of cleaned LFG. The EPA seeks comment on whether the parity that is observed in the delivered vehicle drive energy between the two pathways should be reflected by the quantity of RINs generated by the two pathways and requests comment on the appropriate means of doing so.
One means of ensuring that the Gas and Electric pathways for LFG would generate commensurate quantities of RINs would be to have RIN generation be tied to the quantity of LFG consumed. However, the EPA has concerns regarding the potential generation of RINs from LFG prior to the generation of electricity as this may create a perverse incentive for generators to operate inefficiently. Put
Unlike the chemical fuels typically used to generate RINs under the RFS program, which incur very minimal loses from the time they are produced until they are consumed in the vehicle, renewable electricity used as a transportation fuel presents some unique challenges. As a result, one of the requirements being considered for parties interested in generating RINs for renewable electricity is for the parties to ensure that a corresponding quantity of biogas-generated electricity is produced to provide the ultimate kWh converted to transportation fuel. One interpretation of this provision is that RINs would be awarded exclusively based on the quantity of kWh increased in the battery of the EV being fueled, and should therefore account for the efficiency of the charging system used. The degree to which this value varies from the quantity of kWh used to charge the vehicle's battery is a function of the efficiency of the charging system used to alter the battery's state of charge. Depending on whether a system is inductive or conductive, level I, II, fast charging, or something yet to be developed, there will be associated charging losses. Additionally, the electricity must be generated at facilities that vary in the efficiency by which they convert landfill gas to renewable electricity. There is potential for variation in every energy conversion or transfer process associated with the electricity RIN generation pathway. Furthermore, the transmission of electricity across the country incurs resistive losses, which result in approximately 6 percent of the originally generated kWh being lost before it can even begin the process of being converted to transportation fuel. We request comment on the degree to which parties interested in generating RINs for renewable electricity should be responsible for accounting for electricity generation efficiency and the losses associated with EV charging efficiency and the transmission of electricity.
A related complexity for properly determining the amount of RINs to be awarded for a charging event is parasitic and vampire losses. Unlike their ICE counterparts, EVs cannot utilize waste engine heat for passenger compartment heating and must use electricity, which would otherwise be used to propel the vehicle, to warm the passenger compartment. Additionally, parasitic losses associated with maintaining battery pack temperature, providing passenger compartment air conditioning, etc., can amount to a non-trivial quantity of electricity not being used to propel the vehicle. The combined effect of these system losses will inevitably result in less vehicle miles being driven on a given charge than would otherwise be anticipated under more mild conditions. We request comment on whether or not parasitic and vampire losses should be accounted for in determining the number or RINs that should be generated for renewable electricity, as well as options for accounting for these losses.
Finally, the environmental attributes associated with a unit of generated electricity have value above and beyond wholesale electricity depending upon generation source and local environmental compliance market conditions. Several states and regions currently have programs that require electric utility companies to produce or procure an allotment of renewable energy credits (RECs) to be retired annually in order to promote the buildout of renewable electricity. There are also FTC regulations that ensure consumers who purchase products based on advertised reduced environmental impact that these claims are substantiated. Although RIN generation under the RFS program is not constrained by state laws, it is the responsibility of the regulated community to ascertain the extent to which RIN generation under the RFS program has implications for their actions and obligations under state programs and laws administered by other federal agencies.
Several parties have suggested that the equivalence value for renewable electricity should reflect the higher efficiency of electric vehicles. Deviating from the current system for determining the equivalence value, where the number of RINs generated is calculated strictly on the energy content of the fuel entering the vehicle, to a system that also considered the engine and vehicle efficiency would introduce significant complexity to the RFS program. Engine efficiencies vary not only according to fuel type (
Another issue for consideration is that the EPA currently administers programs beyond the scope of the RFS (such as the Light Duty Vehicle and Heavy Duty Vehicle GHG Standards) that already take into consideration and provide credit for engine and vehicle efficiency. Including vehicle efficiency in RIN determination would result in counting the same benefit under multiple programs. For example, if the vehicle manufacturer approach were ultimately selected as the RIN generation structure and an equivalence value that preferentially rewarded the electricity pathway for LFG adopted, vehicle manufacturers would essentially be receiving large quantities of credits for producing EVs under both the RFS program and the Light Duty Vehicle GHG Standard. Such “double dipping” may be perceived as unwarranted and inequitable by the taxpayers supporting those programs and the consumers purchasing those vehicles. Similar examples of “double dipping” could be postulated for other RIN generation structures. For example, the utility structure where electricity produced from LFG is already accruing a production tax credit of $11/MWh for the plant operator. Providing an additional incentive through the value of the RIN in the RFS program would therefore be providing two incentives for the same engine efficiency benefit. We seek comment on the appropriateness of doing so and introducing vehicle/engine efficiency into the RIN value for RINs generated
The EPA believes that the best-case scenario would be the adoption of a structure for generating RINs for renewable electricity that would simultaneously provide greater incentive for EV use and ownership, increase the amount of renewable electricity produced, and minimize challenges related to program oversight. The discussion of potential program structures is meant to elicit comment on the mechanics of the program, what is most likely to be directly incentivized by each, and which entities should ultimately be able to generate RINs in a manner that will minimize the administrative burden of participation for both the RIN-generating entities and the EPA. By opening up for comment the subject of the equivalence value for RINs generated for renewable electricity, the EPA hopes to receive public comment from all stakeholders to better inform any changes to the RIN values in the future. This program represents an opportunity to incentivize more widespread adoption of EVs, but decisions regarding which structure(s) should be adopted, how and at what point RINs should be generated, and what types of data and oversight should be required will ultimately determine the successfulness of any future program. While we are not proposing a particular structure at this point in time, we do recognize the importance of resolving this issue as quickly as possible to support the growth of renewable electricity and electric vehicles. As such, we request not only comments that comprehensively address the range of issues raised in this discussion, but also supporting data that might allow us to move quickly to a proposal.
Currently, obligated parties report the total volume of gasoline and diesel fuel that they produce or import. This volume is used to calculate their RVOs. In order to more effectively ensure compliance, we are proposing to revise the RVO reporting requirements for obligated parties as described in 40 CFR 80.1451(a) in two ways. First, we are proposing that obligated parties would now report the constituent products described in 40 CFR 80.1407(c) and (e) separately, instead of in total beginning with the 2017 compliance year. This would enable the EPA to more easily track the production of gasoline and diesel by obligated parties and verify that the reported volumes are accurate.
Second, beginning with the 2017 compliance year, we are also proposing to require that obligated parties report heating oil production volumes as part of their annual compliance reports to help ensure that RVOs are appropriately calculated. While heating oil production is not counted towards an obligated party's RVO, it is often chemically identical to diesel fuel. Numerous states and cities in the Northeast and Mid-Atlantic
In the RFS2 final rule,
The RFS regulations currently define “corn oil extraction” as “the recovery of corn oil from the thin stillage and/or the distillers grains and solubles produced by a dry mill corn ethanol plant, most often by mechanical separation.”
Based on currently available information, the indirect GHG impacts of using corn oil recovered through means other than corn oil extraction as a biofuel feedstock are likely to be different than the GHG impacts for corn oil extraction that the EPA modeled for the RFS2 final rule. The corn fractionation and wet milling processes to recover corn oil are not covered either by the existing definition or the proposed definition of “corn oil extraction.”
In the RFS2 final rule, we determined that waste grease biodiesel achieved an 86 percent reduction in lifecycle GHG emissions compared to the baseline diesel fuel. This analysis formed the basis for our determination that the biodiesel from biogenic waste oils/fats/greases would qualify for generation of biomass-based diesel (D-code 4) and advanced biofuel (D-code 5) RINs. These pathways are specified in Rows F and H of Table 1 to 80.1426.
We have received a request to approve a pathway for the use of non-cellulosic portions of separated food waste to produce biodiesel. The process by which the food waste would be converted to biodiesel is similar to the process we modeled in the RFS2 final rule for waste oils/fats/greases biodiesel. In addition, as a waste product, separated food waste would have negligible GHG emissions associated with its production, as is the case for waste oils/fats/greases. Therefore, we believe that utilizing separated food waste to produce biodiesel would have a similar lifecycle emissions profile as using biogenic waste oils/fats/greases to produce biodiesel. As a result, we are proposing to amend the pathways specified in Rows F and H of Table 1 to 80.1426 to allow for the generation of D-code 4 and D-code 5 RINs for the production of biodiesel and advanced biofuel, respectively, from the non-cellulosic portions of separated food waste. This amendment is consistent with the CAA, which defines both biomass-based diesel and advanced biofuels as fuels that result in at least 50 percent less GHG emissions than the petroleum fuels they replace.
For the same reasons, and to provide more flexibility to renewable fuel providers, we are also proposing that renewable diesel made from the non-cellulosic portions of separated food waste would qualify for the generation of D-code 4 and D-code 5 RINs. This additional flexibility is also reflected in proposed amendments to Rows F and H of Table 1 to 80.1426.
The CAA and the EPA's implementing regulations provide for two exemptions to the otherwise generally applicable requirement that all qualifying renewable fuel attain at least a 20 percent lifecycle GHG reduction as compared to baseline petroleum fuel. The first exemption is for a baseline volume of fuel from facilities that commenced construction prior to December 19, 2007, and completed construction by December 19, 2010, without an 18 month hiatus in construction.
Although the EPA envisioned that it would stop processing registration requests for facilities claiming an exemption from the 20 percent GHG reduction requirement after the regulatory July 1, 2013, deadline, we have exercised our discretion to review a number of additional requests on a case-by-case basis. Since the July 1, 2013, deadline, we have accepted approximately 12 requests for either new registrations or for amendments to the registered baseline volume of exempt fuel at a facility. We are aware of approximately 13 additional requests of this nature pending with the EPA, but expect that there may be additional applications undergoing initial processing by EPA contractors.
The EPA is proposing November 16, 2016, as a firm cut-off date for the receipt by the EPA of registration materials related to facilities not previously registered with the EPA that seek to produce renewable fuel exempt from the 20 percent GHG reduction requirement, and for currently-registered facilities that seek to amend their registrations to increase the registered baseline volume of renewable fuel exempt from the 20 percent requirement. The primary reason for this proposed change is that it has become increasingly difficult for EPA staff to independently verify the authenticity of the air permits, construction permits, or similar documents that are in some cases over 10 years old, to determine whether a complete set of such permits has been provided by the would-be registrant, or, in the alternative where permitted capacity cannot be determined, to verify the actual production volumes from facilities during historic time periods. Thus, we believe this proposal is justified for the reason expressed in the current regulation—that registration applications, cannot be verified by the EPA in the same manner as would have been possible with a timely submission. While this may also be the case for submissions received prior to November 16, 2016, we are proposing to review those submissions on a case-by-case basis. A secondary basis for our proposal is related to the first. The later the date of registration submissions that are based on data pre-dating 2007 or 2009, the greater the burden on EPA staff to attempt to verify the claims. This additional burden prevents or limits EPA staff from timely attending to other critical implementation and enforcement matters.
Although there is scant legislative history for EISA to shed light on the purposes of the statutory exemptions from the 20 percent GHG reduction requirement, we believe it is likely that the primary purpose of the exemptions was to protect facilities that had made substantial investments to supply biofuels to the U.S. market in response to the incentives provided by Energy Policy Act of 2005, and that might be financially unable to upgrade their facilities to meet the new 20 percent GHG reduction requirement imposed by EISA. We believe that all such facilities
It should be noted that this proposed change would not affect facilities that have already registered with the EPA and are producing renewable fuel pursuant to an exemption from the GHG reduction requirements under the provisions of 40 CFR 80.1403. Those companies would continue to be able to produce renewable fuels that are exempt from the 20 percent GHG reduction requirement, up to their individual baseline volumes. In addition, facilities can register with the EPA at any time for the production of fuels meeting the 20 percent (or greater) lifecycle GHG emissions reduction thresholds applicable to non-exempt renewable fuel.
Given the dynamic nature of the renewable fuels marketplace, facilities are frequently bought and sold, and this proposal is not intended to change the existing practice allowing facilities that change ownership to retain the exemptions available in 40 CFR 80.1403. We are proposing to add language to the regulations to make clear that when a facility is transferred, the new owners are able to register to produce renewable fuel subject to an exemption in 40 CFR 80.1403 to the extent the prior owner's registration reflects eligibility for such an exemption, provided of course that other regulatory requirements are satisfied.
Taken together, these proposed changes would not allow registration of facilities claiming new or expanded exempt baseline volumes if their requests were received by the EPA after November 16, 2016, but would not impact the operations or eligibility for producing fuel pursuant to the exemptions in 40 CFR 80.1403 for facilities that are already registered. If finalized, the EPA would undertake a case-by-case review of all registration applications received prior to November 16, 2016, to ascertain if the claims for eligibility to produce biofuel exempt from the 20 percent GHG reduction requirement are accurate and verifiable, and requests received after that date would be denied for the reasons stated above.
The EPA proposes to amend 40 CFR 80.1440 to allow parties that blend renewable fuel to produce fuels for use as transportation fuel, heating oil, or jet fuel under a national security exemption or that sell neat renewable fuel for use in vehicles, engines, and equipment that have a national security exemption for emissions certification to delegate to an upstream party the RIN-related responsibilities (
The EPA believes that it would be appropriate to allow DOD or its contractors to delegate RFS RIN responsibilities to upstream parties; doing so would remove a potential obstacle to the use of renewable fuels by DOD and would promote use of renewable fuel by the military. Therefore, we are proposing similar upstream delegation provisions for neat and blended renewable fuels supplied to DOD under a NSE as those already in place for small renewable fuel blenders. The EPA seeks comment on whether this is appropriate.
We are proposing to amend the definition of heating oil in 40 CFR 80.1401. This amendment would expand the current definition of heating oil to include fuels that differ from those meeting the current definition only because they are used to cool, rather than heat, interior spaces of homes or buildings to control ambient climate for human comfort. We are also proposing to make minor modifications to the registration, reporting, PTD, and recordkeeping requirements for renewable heating oil to correspond with this change. We have received questions related to the use of renewable heating oil in equipment that cools interior spaces. We believe that displacing the use of petroleum based fuel oil with renewable heating oil for cooling is consistent with the CAA section 211(o) requirements and should be allowed. We seek comment on whether this approach is appropriate.
We are proposing to amend the RFS registration procedures for separated food waste plans. The current regulations require that plans include: “(1) The location of any municipal waste facility or other facility from which the waste stream consisting solely of separated food waste is collected; and (2) A plan documenting how the waste will be collected, how the cellulosic and non-cellulosic portions of the waste will be quantified, and for ongoing verification that such waste consists only of food waste (and incidental other components such as paper and plastics) that is kept separate since generation from other waste materials.”
Recognizing that business relationships for recovery of food wastes evolve and that a renewable fuel producer may elect over time to purchase feedstocks from different or multiple parties, the EPA proposes to remove the requirement to provide the location of every facility from which separated food waste feedstock is collected. It should also be noted that renewable fuel producers are required to retain records that contain this information under the recordkeeping requirements under 40 CFR 80.1454. The RFS regulations only allow renewable fuel producers to generate RINs for fuel if they can demonstrate, pursuant to the recordkeeping requirements, that the fuel was produced from renewable biomass. The recordkeeping section of the regulations requires renewable fuel producers to
We are also proposing to modify the regulations to specify that separated food waste plans identify the type(s) of separated food waste to be used and the type(s) of establishment the waste will be collected from. For instance, CAA section 211(o) identifies “recycled cooking and trap grease” as an example of a type of separated food waste. Examples of types of establishments could be restaurants, slaughterhouses, or specific food production plants (the kind of food production should be provided). We believe this information is necessary for the EPA to determine whether a renewable fuel producer can make fuel from its proposed feedstock under currently approved separated food waste pathways. Without this information, we would not know what the specific feedstock is (
We are also proposing to require that producers of renewable fuels made from biogenic waste oils/fats/greases that are not separated food waste to submit a plan at registration with many of the same requirements as the plan for producers of renewable fuels made from separated food waste. We would henceforth refer to such plans as “waste oils/fats/greases feedstock plans.” There is significant overlap between the two categories of feedstock, with a considerable quantity of biogenic waste oils/fats/greases qualifying as renewable biomass as a result of its additional qualification as separated food waste. For these reasons, the EPA has required parties intending to use biogenic waste oils/fats/greases as a renewable fuel feedstock to submit separated food waste plans at registration. In addition to helping the EPA determine if the feedstock in question meets renewable biomass requirements, the EPA has found that the plans help the EPA assess whether the feedstocks specified by a prospective producer qualify as biogenic waste oils/fats/greases. This assessment is made on a case-by-case basis. This proposed amendment will conform the regulations to the EPA's current practice. A party fully describing their feedstock in a separated food waste plan would not be required to submit an additional waste oils/fats/greases plan. Since most, if not all, producers of renewable fuel from biogenic waste oils/fats/greases have submitted a separated food waste plan at registration, we do not believe that this revision would add much, if any, burden to existing registered facilities. We propose that those few registered producers using biogenic waste oils/fats/greases who have not previously submitted a separated food waste plan at registration or in a subsequent registration update would be required to do so as part of their next periodic registration update. We seek comment on whether requiring waste oils/fats/greases feedstock plans for producers of renewable fuels from biogenic waste oils/fats/greases is appropriate and whether we should require any additional information.
We are proposing to amend the RFS registration, EMTS reporting, and RIN generation requirements to more explicitly outline requirements for renewable fuel producers that transfer the ownership of a facility that was registered immediately preceding the sale. Throughout the implementation of 40 CFR part 80 fuels programs (
First, we are proposing that the regulations explicitly note that RINs cannot be generated nor assigned to any batches of renewable fuels in EMTS until a renewable fuel producer has completed all applicable registration requirements and the EPA has accepted that renewable fuel producer's registration. Although this requirement is apparent under the current regulations, since the requirements for RIN generation at 40 CFR 80.1426 only allow for the generation of RINs if all registration requirements under 40 CFR 80.1450 are satisfied, we believe that the requirement can be re-iterated for additional clarity.
Second, we are proposing specific requirements for parties that are assuming ownership of a facility that was already registered by another renewable fuel producer. The renewable fuel producer that would newly acquire the previously registered facility would have to submit all applicable registration information required for the registration of a new renewable fuel producer, an appropriately conducted engineering review, and a letter from the responsible corporate officers (RCOs) of both companies notifying the EPA of the date the transfer of ownership is expected to take place. In addition, proof of sale would need to be submitted after the transfer of ownership is completed. Consistent with the requirements of the registration of a new renewable fuel producer, the new renewable fuel producer would need to supply all information to the EPA (with one exception noted below) 60 days prior to the generation of RINs.
The only exception to the 60-day requirement would be that the new renewable fuel producer may supply the proof of sale or ownership within three business days of the effective date of the transfer of ownership. We recognize that it will likely be impractical for parties to provide appropriate proof of sale or ownership until on or after the actual effective date of the transfer of ownership. Therefore, we are proposing to allow some flexibility on when renewable fuel producers may submit the proof of sale or ownership. The EPA would be able to review all other registration materials well in advance of the effective date of the transfer of ownership and be in a position to approve the new renewable fuel producer's registration shortly after receiving the proof of sale or ownership.
Third, we are proposing that the regulations state that the EPA has the sole discretion to allow the new renewable fuel producer to retroactively generate RINs for renewable fuel produced and sold in the interim between the effective date of transfer of ownership of the facility and EPA acceptance of new registration materials. With EPA approval, the RINs could be assigned in EMTS and back-
Taken together, we believe these changes outline what requirements parties are required to meet to register a facility that is changing ownership. We also believe that the proposed changes would allow the EPA the flexibility to work with parties to ensure that companies can continue operation of the facility and generate RINs, when appropriate. We seek comment on whether there are any additional requirements we should specify for parties that are assuming the ownership of a facility, and whether our proposed approach is appropriate.
Independent third-party auditors and professional engineers play critical roles in ensuring the integrity of the RFS program and if renewable fuel is allowed to be produced through the use of biointermediates as we are proposing, there will be a significant expansion in the scope and number of regulated entities under the RFS program, making third-party verifications even more critical. However, in recent years the EPA has taken a number of enforcement actions against renewable fuel producers that generated invalid RINs,
We are also proposing several changes to the requirements for the professional engineer serving as an independent third-party conducting an engineering review for a renewable fuel producer as part of the RFS registration requirements and/or conducting other duties in connection with a renewable fuel producer's registration updates. First, we are proposing to strengthen the independence requirements for third-party professional engineers by requiring those engineers to comply with similar requirements (including the additional requirements we are proposing) to those that currently apply to independent third-party auditors. Second, we are proposing that the third-party professional engineer would be required to register directly with the EPA (as is currently required for third-party auditors). This includes submission of documentation that the third-party engineer meets minimum qualifications (
As discussed extensively in the EPA's Accidental Release Prevention Requirements: Risk Management Programs under the Clean Air Act proposed rule,
• Acting impartially when performing all auditing activities.
• Not having conducted research, development, design, construction, or consulting services for the producer within the last three years.
• Not providing business or consulting services for the producer for a period of at least three years following submission of the final QAP audit for the producer.
• Ensuring that all personnel involved in audit activities for a specific producer do not accept future employment with that producer for a period of at least three years following submission of the final QAP audit for the producer.
These provisions are intended to prevent third-party auditors from expecting, anticipating, or conducting prospective “cross-selling” of other services unrelated to the QAP verification. They are also intended to prevent third-party auditors from seeking or obtaining employment from producers for which the auditors are conducting QAP verification activities. In both instances, we believe that third-party auditors could be unduly influenced in their QAP verification activities as a result. With regard to companies that employ personnel who previously worked for or otherwise engaged in consulting services with a producer, those companies meet the independence criteria when such personnel do not participate on, manage, or advise the audit teams. Additionally, employees of these companies are not prohibited from accepting future employment with a producer as long as they were not involved in performing or managing the audit.
Additionally, we are proposing to preclude third-party auditors from providing initial and triennial engineering reviews for the same renewable fuel producers. In the RFS QAP final rule, we stated that we continued to be concerned that allowing an auditor to also perform engineering reviews and attest engagements will tie the auditor's financial interests too closely with the renewable fuel producers being audited and could create incentives for auditors to fail to report potentially invalid RINs; however, we did not want to exclude potential third-party auditors that had significant knowledge of the RFS program and renewable fuel production facilities from participating in the QAP program.
We seek comment on whether these criteria are appropriate and sufficient to prevent any conflict of interest or the appearance of any conflict of interest between the third-party auditor and the renewable fuel producer and to provide maximum assurances that RINs are being generated validly. We seek comment on whether any adjustments to these criteria are necessary for maximum effectiveness and efficiency, including comments or suggestions on how to provide more flexibility into these criteria. We also seek comment on whether the proposed three-year timeframe to separate the audit from other business arrangements is appropriate.
In 2013, a report from the Inspector General for the EPA highlighted concerns with the independence requirements of third-party professional engineers in the RFS program.
Engineering reviews from independent third-party professional engineers are integral to the successful implementation of the RFS program. Not only do they ensure that RINs are properly categorized, but they also provide a check against fraudulent RIN generation. As we have designed our registration system to accommodate the association between third-party auditors and renewable fuel producers to implement the RFS QAP, we have realized that both the way engineering reviews are conducted and the nature of the relationships among the third-party professional engineers, affiliates, and renewable fuel producers are analogous to third-party auditors and renewable fuel producers. As a result, we are proposing to strengthen the independence requirements for third-party professional engineers by requiring those engineers to comply with similar requirements (including the additional requirements we are proposing) to those that currently apply to independent third-party auditors. We seek comment on whether the independence requirements that apply to third-party auditors should also apply to third-party professional engineers, and whether any adjustments to the third-party auditor independence criteria are necessary for third-party engineers.
We are also proposing that third-party professional engineers become regulated parties under the RFS program and register with the EPA. Requiring third-party professional engineers to register would allow the EPA to determine that the basic minimum qualifications (
Currently, third-party professional engineers conduct the engineering review and often provide the report for submission to the renewable fuel producer, who must then submit the report to the EPA. This creates an opportunity, or at least the perception of an opportunity, for the renewable fuel producer to alter the information submitted to the EPA. Additionally, renewable fuel producers have several options for submitting their engineering review to the EPA: (1) A hard-copy typically as a written report and attachments in a three-ring binder sent through the mail; (2) An engineering review form with accompanying report and attachments in PDF format uploaded to the EPA's registration system (CDX or OTAQREG); or (3) Submission using an EPA-developed electronic webform. The current submission of hard-copy engineering reviews presents a significant administrative burden on EPA staff to process the mail, scan the engineering review report, and upload it to the EPA system to route to the team for review. The hard-copy engineering reviews also create a large volume of paper records that the EPA must further store and protect following CBI requirements, as appropriate. By requiring engineering reviews to be submitted electronically, the EPA would be able to reduce the administrative burden of processing these reports, as well as reduce a significant amount of paper that is used since these reports are typically hundreds of pages long. This proposed change may reduce burden for the submitters as well.
These proposed requirements would eliminate the current options for renewable fuel producers to submit engineering review reports directly to the EPA and for third-party professional engineers to submit engineering review reports in hardcopy via the mail, which could be a concern for some parties. We seek comment on these proposed changes.
If the proposed changes to engineering reviews are finalized, we plan to develop and require a new electronic webform for engineering reviews reflecting those changes at some point in the future. The added benefits of the electronic reporting form are a reduction in errors and omissions for engineering reviews and a more IT-accessible format that would reduce the amount of time that the EPA takes to review and accept RFS registrations. This should allow EPA acceptance of registrations for renewable fuel producers in a timelier manner. However, since the electronic webforms for the engineering reviews may require the EPA to develop new or revise existing systems, including troubleshooting, we may require significant time to fully implement this component after the effective date of these requirements.
We are also proposing to improve the RFS registration requirements for engineering reviews by requiring site visits to take place when the facility is producing renewable fuel. This will provide the regulated community and the EPA with greater confidence in the production capabilities of the renewable fuel facility. Since the adoption of the RFS2 requirements in 2010, most engineering reviews are conducted by a handful of third-party professional engineers. Some of these engineers are using templates that make it difficult for the EPA to determine whether registration information was verified. We are concerned that, in some instances, the third-party engineers are relying too heavily on information provided by the renewable fuel producers, and not conducting a truly independent verification. In order to provide greater confidence in third-party engineering reviews, we are proposing that the engineering review submission include evidence of a site visit while the facility is producing renewable fuel(s) that it is registered to produce. We also propose to incorporate the EPA's current interpretation and guidance into the regulations regarding actions that third-party engineers must take to verify information in the renewable fuel producer's registration application. The amendments would explain that in order to verify the applicable registration information, the third-party auditor must independently evaluate and confirm the information, and cannot rely on representations made by the renewable fuel producer. We believe these amendments would help provide greater assurance that third-party professional engineering reviews are based upon independent verification of the required registration information in 40 CFR 80.1450, helping to provide enhanced assurance of the integrity of the registration materials submitted by the facility, as well as the renewable fuel they produce.
Finally, we are proposing prohibited activities for third-party professional engineers. Specifically, we are proposing to prohibit third-party professional engineers from failing to identify incorrect information in a renewable fuel producer's registration, failing to properly conduct an engineering review, failing to disclose to the EPA any financial, professional, business, or other interest with parties for whom the third-party professional engineer provides services for under the RFS registration requirements. The EPA staff that review RFS registrations have concerns that third-party professional engineers may be acting, independently or through an affiliate, as consultants and agents for the same renewable fuel producer, or that, directly or through an affiliate, they may have a financial interest in the renewable fuel producer, may not appropriately conduct engineering reviews, or may not meet the requirements for independence to qualify as a third-party. We believe that making third-party professional engineers more accountable for properly conducting engineering reviews under the regulations and requiring that they interact more directly with the EPA will help our ability to identify potential conflicts of interests and bring enforcement actions against third-party professional engineers should an issue arise.
We seek comment on these proposed changes and input on whether there is anything else the EPA should do to help ensure that third-party professional engineering reviews are conducted so as to maximize the submission of relevant and accurate information to the EPA.
We are proposing additional circumstances in which the EPA may deactivate the registration of a company, third-party auditor, or third-party engineer under 40 CFR 80.1450(h). In July 2014, the EPA finalized requirements that describe circumstances under which the EPA may deactivate a company registration and an administrative process to initiate deactivation that provides companies an opportunity to respond to and/or submit the required information in a timely manner.
• The company, third-party auditor, or third-party engineer fails to comply with the registration requirements of 40 CFR 80.1450.
• The company, third-party auditor, or third-party engineer fails to submit any required report within thirty days of the required submission date.
• The company, third-party auditor, or third-party engineer fails to pay a penalty or to perform any requirements under the terms of a court order, administrative order, consent decree, or administrative settlement agreement between the company and the EPA.
• The company, third-party auditor, or third-party engineer submits false or incomplete information.
• The company, third-party auditor, or third-party engineer denies the EPA access or prevents the EPA from completing authorized activities under CAA section 114 despite our presenting a warrant or court order. This includes a failure to provide reasonable assistance.
• The company, third-party auditor, or third-party engineer fails to keep or provide the EPA with the records required in 40 CFR 80.1450.
• The company, third-party auditor, or third-party engineer otherwise circumvents the intent of the CAA or 40 CFR part 80, subpart M.
These deactivation circumstances are consistent with cases where the EPA may deny or revoke a certificate of conformity under 40 CFR 1051.255(c) and 86.442-78 for engines and vehicles manufactured in or imported into the U.S. In addition, we are proposing that in instances of willfulness or those in which public health, interest, or safety requires otherwise, the EPA may also deactivate the registration of a company, third-party auditor, or third-party engineer registration without providing notice to the company, third-party auditor, or third-party engineer prior to deactivation, and would send written notification to the RCO describing the reasons for the deactivation. Companies, third-party auditors, or third-party engineers could still submit new registrations after appropriate actions were taken by the company, third-party auditor, or third-party engineer.
We believe these proposed amendments would help parties better understand when the EPA intends to restrict a party's participation in the RFS program as well as the procedures that will be used in such circumstances. We seek comment on whether there are any additional circumstances when the EPA should deactivate the registration of a company, third-party auditor, or third-party engineer.
Consistent with our proposed approach for biointermediate producers, we are proposing that biogas producers whose biogas is used to produce renewable electricity or CNG/LNG would be required to register with the EPA and would be liable for violations of the applicable RFS requirements, and that renewable fuel producers may only generate RINs for renewable fuel produced from biogas sourced from a registered biogas producer.
We are proposing to create a new section in the RFS regulations for RIN retirements. The regulations have specific sections that address when and how parties may generate and separate RINs. However, the cases where parties must retire RINs are identified in various sections throughout the regulations. The new section of the RFS regulations for RIN retirements would simply organize these current sections into one place. The EPA is aware of some confusion for some responsible parties causing those parties to improperly retire RINs or fail to retire RINs when they have a responsibility to do so under the regulations. Improper retirements can lead to a time-consuming remediation process, both for the EPA and responsible parties. This new section attempts to organize these requirements into one location in the regulations to make these determinations simpler to locate and understand.
We are also proposing new regulatory language for cases requiring RIN retirement that are identified in EMTS, but may not be clear in the regulations, given their current organization. Our intent is not to add additional burden on parties that must retire RINs under the RFS program, but rather to make the regulations consistent with how parties retire RINs in EMTS and help reduce potential confusion regarding the situations when parties must retire RINs.
Taken together by enumerating the specific instances in which a party must retire RINs in a new specific section of the regulations and by making those retirements consistent with how parties administratively retire RINs in EMTS, we believe that the newly proposed RIN generation section would provide beneficial clarification.
One of the potential technologies that may be enabled to participate in the RFS program by the proposed regulations for biointermediates is the production of bio-oil from cellulosic feedstocks. While these bio-oils can be upgraded to finished transportation fuels at stand-alone facilities that process only renewable biomass and RINs can be generated for these fuels under the existing RFS regulations, it may be more efficient and cost-effective to upgrade these bio-oils along with petroleum crude oils at existing refineries. Currently, pathways exist for renewable gasoline and gasoline blendstock (Pathway M in Table 1 to 40 CFR 80.1426) and naphtha (Pathway N in Table 1 to 40 CFR 80.1426) produced from cellulosic biomass that is co-processed with petroleum. However, there is currently no pathway for diesel,
The current pathway for cellulosic diesel, jet fuel, and heating oil (Pathway L in Table 1 to 40 CFR 80.1426) excludes processes that co-process renewable biomass and petroleum. To qualify as cellulosic diesel, a fuel must meet the requirements for both cellulosic biofuel and biomass-based diesel. The definition of biomass-based diesel explicitly excludes renewable fuels that are derived from co-processing biomass with petroleum, and therefore a process that produces diesel, jet fuel, or heating oil by co-processing renewable biomass with petroleum cannot qualify as biomass-based diesel or cellulosic diesel under Pathway L in Table 1 to 40 CFR 80.1426. The EPA is proposing a new pathway that would allow these fuels to qualify as cellulosic biofuel and generate cellulosic (D-code 3) RINs, as cellulosic biofuels that are not prohibited from being derived from biomass co-processed with petroleum. We are also proposing to amend the definition of cellulosic diesel to no longer require that it meet the definition of biomass-based diesel, and proposing to create a new definition for cellulosic biomass-based diesel to refer to fuels that meet the definition for both cellulosic biofuel and biomass-based diesel. Fuels that meet the cellulosic biomass-based diesel definition would be able to generate D7 RINs, while fuels that meet the cellulosic diesel definition but not the cellulosic biomass-based diesel definition due to co-processing with petroleum would be able to generate D3 RINs.
We believe that the lifecycle modeling that was done for the current pathway for cellulosic diesel, jet fuel, and heating oil provides sufficient basis for concluding that fuels produced using similar processes and technologies, where the only difference is that the bio-oil is co-processed with petroleum, meet the appropriate GHG reduction thresholds. Any emissions related to the transportation of bio-oil from the production site to a refinery or other facility that co-processes renewable biomass with petroleum to produce transportation fuel is not expected to have a significant impact on the emissions of these fuels. We seek comment on whether this proposed approach is appropriate.
Vegetable oils (
As an initial matter, the EPA is proposing two regulatory definitions for vegetable oil that differentiate between its use as a feedstock and its use as a renewable fuel. When vegetable oil is used as a feedstock, we propose to refer to it as “straight vegetable oil (SVO)”. If the same material is used as renewable fuel (either in a blend with petroleum diesel or in neat form for use in a modified engine), we propose to refer to it as “viscous non-ester renewable diesel (VRD).” RINs would not be generated for SVO because it is intended to be used as a feedstock rather than as a renewable fuel, but RINs could be generated for VRD under appropriate conditions.
However, to avoid the enforcement problems noted above, we are proposing unique provisions related to RIN generation for VRD. Although under the RFS program it is generally the renewable fuel producer that generates RINs for renewable fuel, we propose that for VRD this would only be the case if it is intended to be used in its neat form. Furthermore, in such circumstances the producer would be required to demonstrate in their registration submission that an end-user has: (a) Modified engines to operate on the fuel in accordance with an EPA-approved Clean Alternative Fuel Conversion under 40 CFR part 85, subpart F; and (b) contracted with the producer to use the neat VRD as transportation fuel, heating oil, or jet fuel. Given that there are relatively few such EPA-approved Clean Alternative Fuel Conversions, it should not be difficult for the EPA to establish that an end-user has made the necessary modifications at the time of VRD producer registration and would help ensure that RINs are only generated for fuel that is actually used as transportation fuel, heating oil, or jet fuel. Additionally, we are proposing that the VRD producer would need to have the use of the neat VRD verified by a third-party auditor under the QAP program prior to RIN generation.
In instances where VRD is to be blended with petroleum diesel, we propose that the only party that could generate RINs for VRD would be the party actually doing the blending (
VRD would be defined as a form of “non-ester renewable diesel” which, in turn, is a type of biomass-based diesel. Therefore, biomass-based diesel RINs (D-code 4) could be generated for VRD under the existing renewable diesel pathways in Table 1 to 40 CFR 80.1426. We are proposing to amend the definition of non-ester renewable diesel in two ways. First, it would differentiate between VRD and non-VRD renewable fuels. The definition would clarify that non-VRD renewable fuels must be produced through a hydrotreating
We believe that these proposed amendments would reduce the potential for RIN fraud and provide greater certainty to obligated parties regarding the validity of the RINs they purchase. We seek comment on our proposed approach for vegetable oils, including whether there may be additional scenarios in which it may be appropriate to allow for RINs to be generated by VRD producers.
The EPA is proposing regulations that would streamline our processing of claims that RFS-related information should be withheld from public disclosure under the Freedom of Information Act (FOIA), 5 U.S.C. 552(b)(4), as CBI. If finalized, the rules would identify which types of RFS information would receive confidential treatment as CBI and which would be available for disclosure in response to a FOIA request without the need for the often time-consuming notice and substantiation procedural requirements that would otherwise be required under 40 CFR part 2, subpart B.
The EPA recently received and responded to a FOIA request seeking release of a substantial amount of RFS transactional and compliance information submitted to the EPA through EMTS and in other formats.
In addition, we are proposing to codify a determination that basic information related to EPA actions on petitions for RFS small refinery and small refiner exemptions may not be claimed as confidential business information. Small refineries and small refiners may petition the EPA pursuant to 40 CFR 80.1441 and 80.1442 for an extension of exemptions from RFS compliance obligations on the basis of disproportionate economic hardship. Some petitioners availing themselves of this opportunity have claimed their submissions to be CBI. To the extent that the EPA determines that such CBI claims are justifiable, the EPA protects the information from disclosure to the public pursuant to FOIA Exemption 4, which covers “trade secrets and commercial or financial information obtained from a person that is privileged or confidential.” The EPA generally evaluates CBI claims pursuant to its regulations in 40 CFR part 2, subpart B. While it is appropriate to consider the potential that information that the EPA obtains from outside of the agency, such as detailed business information within a petition submission, could qualify for protection as CBI, the courts have clarified that data generated within the government are not “obtained from a person” within the meaning of FOIA Exemption 4, and therefore cannot be claimed as CBI.
The proposed regulations would specify that with respect to each decision on a small refinery/refiner exemption request, we would release to the public the petitioner's name, the name and location of the facility for which relief was requested, the general nature of the relief requested, the time period for which relief was requested, and the extent to which the EPA granted or denied the requested relief. All of this information is inherent to the EPA's decision and, we believe, is not entitled to treatment as CBI. The EPA could post this information on its Web site, or otherwise provide it to the public in response to individual information requests. If finalized, the procedures in 40 CFR part 2, subpart B, related to EPA processing of requests for documents for which CBI claims have been made would not apply to requests for the information specified in the rule.
We also believe that parties cannot claim as CBI information related to the EPA's internal workload, since the matters that the EPA has decided to work on reflect an EPA decision, and those decisions were not “obtained from a person” outside of government. Thus, we believe that once a small refinery/refiner petition is accepted by the EPA for processing, and added to the queue of projects that are pending EPA evaluation, basic information regarding the matter is not entitled to treatment as CBI. We propose, therefore, to establish by rule that after adding the response to a small refinery/refiner petition to its queue of projects to be completed, the EPA would publicly release information on the name of the petitioner, the name and location of the facility for which relief was requested, the general nature of the relief requested, and the time period for which relief was requested. This basic information is necessary to
Finally, we are proposing that the EPA is not releasing information that is entitled to protection as CBI when it posts on its Web site or otherwise publicly releases EPA enforcement-related determinations or actions, together with basic information regarding the party or parties involved and the RINs in question. The EPA determinations and actions covered by this proposal include EPA determinations that RINs are invalid under 40 CFR 1474(b)(4)(i)(C)(2) and 1474(b)(4)(ii)(C)(2), notices of violation, administrative complaints, civil complaints, criminal informations and criminal indictments. The information that the EPA may post or otherwise publicly release in the context of these determinations or actions includes the company name and EPA identification number of the company that generated the RINs in question, the facility name and EPA identification number of the facility at which the fuel associated with the RINs in question was allegedly produced or imported, the total quantity of RINs in question, the time period when the RINs in question were generated, and the batch number(s) and the D code(s) of the RINs in question. This basic information is central to the EPA's enforcement-related actions and determinations. Since these actions and determinations are not “obtained from a person” outside of the EPA, they and the basic information necessary to describe them cannot be claimed as CBI. Thus, while we are proposing that most RIN-related information is generally entitled to treatment as CBI, as discussed above, we are also proposing as an exception to that general rule that basic RIN information that is central to the EPA's enforcement-related actions and determinations is not entitled to such treatment.
We believe that publicly releasing the EPA's enforcement-related actions and determinations described above is important to successful operation and integrity of the RFS program. Doing so may prevent parties from unwittingly transferring or attempting to use invalid RINs for compliance, in contravention of the RFS regulations, or from investing in invalid RINs that they will be unable to use for compliance. We seek comment on whether any additional factual information relating to the EPA actions described above should be identified as ineligible for CBI protection and whether there are additional EPA actions and determinations that we should identify as including RIN-related information that does not qualify for CBI protection.
We note that existing EPA regulations governing treatment of CBI define the term “person” in 40 CFR 2.201(a) as including government agencies and their employees. We believe that this is appropriate, since we acknowledge that there may be instances where a government report or decision could contain detailed information generated by the EPA, but which is based on information submitted from outside of the EPA and which could create competitive harm to the non-government data submitter if released. We propose to interpret our regulatory definition of “person” in accordance with the court decisions interpreting the phrase “obtained from a person” for purposes of FOIA Exemption 4, to both allow the EPA to withhold EPA-generated records in appropriate circumstances where necessary to prevent disclosure of information obtained from outside the EPA to inform those decisions, and to release basic information related to EPA decisions and workload as proposed in this action. However, we solicit comment on whether the regulatory definition of “person” should be amended to more clearly align with this proposal.
The CAA provides an exemption from the minimum 20 percent lifecycle GHG reduction requirement for a baseline volume of fuel made from two classes of facilities; those that commenced construction prior to the date of EISA's enactment, and ethanol facilities fired by natural gas or biomass that commenced construction prior to December 31, 2009.
To help implement this proposed change, the EPA is also proposing changes to the registration and registration update requirements for renewable fuel producers that either already have facilities registered with an exemption under 40 CFR 80.1403 or renewable fuel producers that have facilities that would have been able to claim an exemption under 40 CFR 80.1403 but cannot due to the proposed change. Since the EPA would no longer need to establish a baseline volume from permits or production information prior to December 19, 2007, or outdated production information, the EPA is proposing that facilities that would have been able to claim the exemption (
To help distinguish total baseline volumes from exempted baseline volumes, the EPA is proposing to redefine the term “baseline volume” and create a definition for “exempted baseline volume.” The proposed definition for exempted baseline volume would include the permitted capacity as established in air permits prior to December 19, 2007 or older production records as defined in the current definition of actual peak capacity. This definition should be consistent with the baseline volumes previously established for facilities claiming an exemption
The EPA is proposing to remove the option that allows a RIN-generating foreign producer to pay the required bond amount to the U.S. Treasury as stipulated under 40 CFR 80.1466(h)(2)(i) instead of obtaining a bond in the proper amount from a third-party surety agent. This option was provided as an alternative approach for RIN-generating foreign producers that expressed possible difficulties in securing the required bond to participate in the RFS program. We are now proposing to remove this option because it has proven to be too much of a challenge for the EPA to implement properly. For instance, a special account would need to be established at the U.S. Treasury that would allow the EPA to deposit the submitted bank checks (or hold in escrow) and also allow the EPA the ability to draw upon these funds to satisfy a potential judgment or reimburse the RIN-generating producer if they no longer participate in the RFS program. This type of accounting requires a lot of oversight and resources to ensure proper implementation. Since there very few RIN-generating foreign producers who are currently using this option, we believe it is not justified to continue to allow this option due to the high administrative burden. For these reasons, we are proposing to remove this option from the regulations and believe this proposal will provide RIN-generating foreign producers with sufficient time to obtain surety agreements to meet the bond requirements. We request comment on this proposed change.
The EPA is proposing to amend the PTD, RIN management and enforcement-related regulations to address situations where a party subject to PTD requirements is aware that renewable fuel it intends to transfer will be used for purposes other than as transportation fuel, heating oil, or jet fuel.
CAA section 211(o)(1)(J) defines “renewable fuel” as fuel that is produced from renewable biomass and that is used to replace or reduce the quantity of fossil fuel present in a “transportation fuel,” which is defined in CAA section 211(o)(1)(L) as “fuel for use in motor vehicles, motor vehicle engines, nonroad vehicles or nonroad engines (except for ocean-going vessels). The CAA also provides, however, that “additional renewable fuel,” defined as fuel made from renewable biomass that is used to replace or reduce the quantity of fossil fuel present in home heating oil or jet fuel, may also receive credit under the CAA. Thus, the CAA envisions use of renewable fuels under the RFS program for transportation fuel, heating oil, and jet fuel, which we refer to here as “qualifying uses.” While some of the more common biofuels that participate in the RFS program (
The original RFS2 regulations required parties that obtained renewable fuel with attached RINs and that either designated renewable fuel for a non-qualifying fuel use or that used renewable fuel for a non-qualifying fuel use to retire the RINs that they received with the fuel.
In one section of the preamble to the final QAP Rule, the EPA stated that it was implementing this proposal.
The EPA recognizes that these contradictory statements have led to confusion, and we are proposing to resolve this confusion by implementing a new 40 CFR 80.1433 that would require a party that receives renewable fuel without a PTD or with a PTD indicating that the fuel is for qualified uses, and that subsequently transfers that fuel to a party that the transferor knows or has reason to know will use the fuel for a non-qualifying use, to include a statement on the PTD designating the fuel for an alternative use and to retire an appropriate number and type of RINs. We are also proposing that the transfer of renewable fuel for use by stationary internal combustion engines would not require RIN retirement. These engines often use the same fuel as nonroad engines, and the effect of renewable fuel in displacing petroleum products in fuel used in such engines is also similar. We are also proposing to add a new prohibited act at 40 CFR 80.1460(j) for failing to retire RINs as would be required by proposed 40 CFR 80.1433. The RIN retirement provisions in proposed 40 CFR 80.1433 would not apply to a party that could demonstrate, through records available at the time of fuel transfer and maintained for five years, that no RINs were generated for any part of the fuel or fuel blend that it transfers or that an appropriate number and type of RINs had already been retired by a prior owner of the fuel or fuel blend. With respect to situations where a party asserts that RINs were never generated, we seek comment on whether the exemption from the RIN retirement requirements in proposed 40 CFR 80.1433 should be limited to those parties that purchased renewable fuel directly from the renewable fuel producer, similar to the requirement specified for exports at 40 CFR 80.1430(a). We believe these proposed provisions, if finalized, will remedy the confusion created by the contradictory statements in the QAP rule, and will further the objectives of the statute by augmenting the integrity of the RIN system.
We are also proposing to delete 40 CFR 80.1460(c)(2) and (c)(3) from the prohibited acts section of the regulations, and replace these sections with a new 40 CFR 80.1460(c)(2). We believe that the existing two near-identically worded provisions would appropriately be replaced by a single more clearly worded regulation that prohibits parties from using RINs for compliance or transferring RINs to other parties, in a situation where the party using or transferring the RINs uses the fuel associated with the RINs for a purpose other than as transportation fuel, heating oil or jet fuel. This prohibition would only apply to parties that obtained renewable fuel with assigned RINs and then used or transferred the renewable fuel for a non-qualifying fuel use; any RINs improperly transferred by such a party would not be considered invalid as a result of that action, and therefore could be used or transferred by downstream parties notwithstanding the upstream violation of 40 CFR 80.1460(c)(2).
The EPA is proposing several changes to its testing requirements, as described in the following sections.
The EPA is proposing to remove the requirement for periodic resubmitting of non-VCSB test methods that have not been approved by VCSBs. Non-VCSB test methods are required to resubmit accuracy and precision qualification information every 5 years if the non-VCSB test method has not been approved by a VCSB organization. At this time, VCSBs, such as ASTM, have yet to qualify any non-VCSB test methods for measuring the sulfur content in diesel, gasoline, butane, or pentane. Moreover, the EPA requires minimal statistical quality control requirements on every type test method approved under the diesel sulfur accuracy and precision requirements
The EPA is also proposing to require use of ASTM D6708 for determining that sample specific biases are random prior to submission for approval. If a non-VCSB test method absolute fuel parameter of sulfur in diesel, gasoline, butane, or pentane as compared to its designated primary test method were to exhibit sample-specific biases that cannot be determined as random through the utilization of ASTM D6708, such an indication of sample-specific biases would raise a concern that the test method should be investigated and improved upon prior to utilization in practice in order to eliminate any systematic errors that may keep the test method from properly measuring sulfur in either diesel, gasoline, butane, or pentane in the most accurate and precise manner practically achievable. The EPA believes that the non-VCSB test method applicant has to demonstrate through ASTM D6708 that sample-specific biases existing between the candidate non-VCSB test method and the designated primary test method are random prior to submitting to the EPA for approval. If the applicant determines that sample-specific biases exist between the candidate non-VCSB test method and the designated primary test method that cannot be determined to be random through utilization of ASTM D6708, then the non-VCSB test method is automatically disqualified from consideration for approval. The EPA is proposing to an additional requirement that non-VCSB test methods for sulfur in diesel, gasoline, butane, and pentane must demonstrate through the use of ASTM D6708 that sample-specific biases are random. This demonstration must be made prior to submission for approval.
Currently, EPA fuels regulations exempt those designated primary test methods that were in use prior to October 28, 2013, from meeting the accuracy and precision qualification requirements.
The EPA is proposing to add accuracy and precision criteria for sulfur in pentane that are identical to sulfur in gasoline. The Tier 3 regulations provided for the allowance of blending pentane in gasoline.
In addition, the EPA is also proposing to establish two ASTM test methods for the analysis of benzene content, aromatic content, and C6-plus hydrocarbons in pentane at 40 CFR 80.46. We are proposing to designate ASTM D6730 as the designated primary test method for measuring benzene content, aromatic content, and C6-plus hydrocarbons in pentane. We are also proposing one alternative test method for the benzene content, aromatic content, and C6-plus hydrocarbons measurement in pentane, ASTM D6729, provided that its test results are correlated to ASTM D6730. Table IX.A.3-1 below lists the two ASTM test methods we are proposing. The establishment of these two test methods would provide greater assurance to both the regulated community and the EPA that benzene content, aromatic content, and C6-plus hydrocarbons in pentane meet the regulatory requirements at 40 CFR 80.86.
We are proposing to add ASTM D5769 as a designated primary test method for benzene in gasoline, gas chromatography mass spectrometry (GCMS)-based test method. This would be in addition to the current designated primary gas chromatography (GC)-based test method (ASTM D3606) codified at 40 CFR 80.46(e). Currently, the majority of motor vehicle gasoline in the U.S. contains ethanol. The current GC-based designated primary test method for benzene in gasoline (ASTM D3606) has the potential for interference issues with ethanol in determining the benzene content in gasoline when ethanol is present as an oxygenate in gasoline. This interference issue of ethanol with benzene peaks in ASTM D3606 makes this test method very difficult to use and has significant potential to impact the accuracy of the benzene content test results.
As previously explained, we are also proposing removal of the sunset date for designated primary test methods. As a result of this removal, the designated primary test methods for benzene in gasoline would be exempt from accuracy and precision qualification requirements at 40 CFR 80.47.
After the Tier 3 rule was published,
The EPA intended for the downstream oxygenate blending regulations at 40 CFR 80.1603(d) to apply to all gasoline and BOBs, not just conventional gasoline and CBOB. In the preamble to the Tier 3 rule, the EPA explained that the “final rule requires that in determining their compliance with today's sulfur standards, refiners and importers must either use the actual sulfur content of the DFE established through testing of the DFE actually blended or assume a 5 ppm sulfur content for the DFE added downstream. To prevent potential bias, a refiner or importer must choose to use only one method during each annual compliance period.”
Although the EPA believes that 40 CFR 80.1603(d) clearly applies to all gasoline and BOBs, not just RFG or RBOB, we are proposing minor amendments to assure that the regulated community will not misinterpret these requirements. We are also proposing minor amendments to the Tier 3 sulfur reporting requirements at 40 CFR 80.1652 to better accommodate the inclusion of downstream oxygenate blending in annual average sulfur compliance demonstrations. These added requirements would help align the reported batch information with the annual average compliance report and is necessary to ensure that refiners met both the per-gallon and annual average sulfur standards. We also seek comment on whether we should adopt similar provisions for the gasoline benzene program.
We are proposing numerous technical corrections to the EPA's fuels programs. These amendments are being proposed to correct inaccuracies and oversights in the current regulations. These proposed changes are described in Table IX.C-1 below. We request comment on all of these proposed changes.
The proposed provisions for biointermediates and the proposed provisions for EFF and gasoline produced at blender pumps would have economic impacts. The proposal would provide significant additional regulatory flexibility, streamlined compliance provisions, and the opportunity for increased biofuel production at reduced cost. The cost savings are anticipated to far outweigh the minor costs imposed for demonstrating compliance. In most cases, the associated costs would only apply to those parties that elect to take advantage of the proposed flexibilities because the potential economic benefits outweigh the costs. This proposal contains minor additional registration, reporting, and recordkeeping requirements that would apply to some parties in the biofuel production and distribution system that do not take advantage of the proposed flexibilities as well as those that do. We are also seeking comment in this action on potential provisions for generating RINs from renewable electricity and seek comment on what economic impacts they may have.
Under the current RFS regulations, the production of renewable biofuels from feedstocks listed in approved pathways must all take place at the same facility. Numerous companies have approached the EPA about the use of biointermediates to produce renewable fuels as part of the RFS program. Many of the biointermediates produced by these companies would be used by renewable fuel producers to generate cellulosic and other advanced renewable fuels. This proposal would allow for the production of renewable fuel from biointermediates by amending the RFS regulations to allow the new flexibility. By allowing producers to use biointermediates to produce renewable fuels, the EPA is enabling the production of potentially significant future volumes of cellulosic and other advanced biofuels at reduced cost.
Without the regulatory flexibilities in this proposed rule, the expansion of blender pumps and use of natural gasoline as an EFF blendstock could not be accommodated while at the same time continuing to ensure the control of emissions from FFVs. We anticipate that the flexibility to use natural gasoline of appropriate quality to produce EFF provided by this proposal could reduce the EFF production cost. For example, we project that the use of natural gasoline to produce E70 in place of gasoline might reduce the cost of E70 by 5 percent on an energy adjusted basis.
Our proposal to regulate E16-50 quality with other higher-level ethanol blends that can only be used in FFVs rather than to continue to treat E16-50 as gasoline would provide a practical and streamlined means for blender pump-refiners to demonstrate compliance while continuing to ensure the environmental quality to these blends. Our proposal to allow gasoline to be made at blender pumps from September 16 through May 31 without triggering the full gasoline refiner requirements would likewise provide a practical and streamlined means for blender pump-refiners to demonstrate
The proposed revisions discussed in sections V, VI, VIII, and IX of this preamble would all help support the RFS and other fuels programs by doing such things as creating new renewable fuel production pathways, clarifying various provisions of the RFS program, and providing numerous technical corrections.
The ability to produce renewable fuels and generate RINs for them using biointermediates holds significant promise for reducing the costs of producing cellulosic and other advanced biofuels. By concentrating renewable fuel feedstocks prior to shipment to the renewable fuel production facility and/or by taking advantage of existing infrastructure, producers can significantly reduce their production costs. At the same time, allowing the use of biointermediates will require some additional minor compliance costs. The proposed provisions for production of renewable fuel from biointermediates include new registration, reporting, recordkeeping, and PTD requirements for biointermediate producers. There would also be additional recordkeeping and reporting requirements for renewable fuel producers that use biointermediates. These requirements are typical of other EPA fuel programs, and the associated costs are modest. As this is a new flexibility that is not currently available to producers in the RFS program, the EPA does not believe that a renewable fuel producer would choose to take advantage of this program unless there was sufficient economic incentive for the producer to do so. Current renewable fuel producers would not be compelled to use biointermediates, and as such, any costs associated with these provisions are purely voluntary.
Overall, we anticipate only a cost savings regarding the cost to produce EFF blends and demonstrate compliance with the EPA fuel quality requirements. This proposal would provide additional flexibility regarding the hydrocarbon blendstocks that could be used to produce EFF. These new flexibilities would apply to all EFF blends. Currently, the only hydrocarbon blendstocks that producers of E85 may use to be assured of compliance with the sub-sim requirement for E85 are certified gasoline and BOBs. Under the proposed EFF bulk blender-refiner provisions, certified natural gasoline EFF blendstock could also be used to produce EFF. The EFF bulk blender-refiner certification option includes streamlined compliance demonstration requirements to limit the testing that would be required when such certified blendstocks are used. We anticipate that the ability to use certified natural gasoline EFF blendstock would be welcomed by EFF bulk blender-refiners due to the anticipated lower cost compared to the use of gasoline or BOBs.
This proposal would also provide streamlined provisions for EFF blender pump-refiners to demonstrate that the blends they produce are in compliance with EPA fuel quality requirements. Under the current regulations, E16-50 blends are treated as gasoline. Consequently, blender pump-refiners are currently subject to all of the requirements of a gasoline refiner, including per-batch testing, registration, and annual reporting. Under this proposal, E16-50 would no longer be treated as gasoline, and would instead be subject to new fuel quality requirements that apply to all EFF (E16-83). This would allow EFF blender pump-refiners to demonstrate compliance with the proposed fuel quality requirements for the EFF they produce by maintaining PTDs for the parent blends they use to make EFF and participating in an EFF quality survey.
Under the current regulations, the production of the E10 or E15 gasoline blends at blender pumps also subjects blender pump-refiners to all of the gasoline refiner requirements. This proposal would provide a streamlined means for producers of gasoline at blender pumps to demonstrate compliance with these gasoline refiner requirements by keeping the PTDs from the parent blends that were used. The proposed provisions for producers of EFF and gasoline at blender pumps are consistent with the common business practices and commensurate with the ability of blender pump-refiners to affect the quality of the EFF and gasoline (E15 and E10) they produce. Hence, we expect that these proposed provisions would substantially reduce the cost of compliance for blender pump-refiners.
The proposed provisions for EFF include new registration, reporting, recordkeeping, PTD, and fuel survey requirements for EFF full-refiners and bulk blender-refiners as well as recordkeeping requirements for distributors and retailers of EFF and manufacturers of additives for use in EFF. To support the proposed provisions to allow the use of certified natural gasoline EFF blendstock, this proposal also includes registration, batch testing, reporting, recordkeeping, and PTD requirements for natural gasoline EFF blendstock refiners and
The EPA does not anticipate that there would be any significant costs associated with the proposed revisions to the RFS and other fuels programs discussed in sections V, VI, VIII, and IX of this preamble.
This action is a significant regulatory action that was submitted to the Office of Management and Budget (OMB) for review because it raises novel legal or policy issues. Any changes made in response to OMB recommendations have been documented in the docket.
The information collection activities in this proposed rule have been submitted for approval to OMB under the PRA. The Information Collection Request (ICR) document that the EPA prepared has been assigned EPA ICR numbers 2545.01 (for the proposed biointermediates provisions) and 2544.01 (for the proposed EFF provisions). You can find a copy of the ICR in the docket for this rule, and it is briefly summarized here.
The information to be collected for the proposed biointermediate provisions are based on the proposed registration, recordkeeping, reporting, and PTD requirements in 40 CFR part 80, subpart M, which would be mandatory for biointermediate producers and renewable fuel producers that use a biointermediate. The proposed recordkeeping, reporting, and PTD requirements require only the specific information needed to determine compliance. All information submitted to the EPA pursuant to the recordkeeping and reporting requirements for which a claim of confidentiality is made is safeguarded according to the EPA policies set forth in 40 CFR part 2, subpart B.
The information to be collected for the proposed EFF provisions are based on the proposed registration, recordkeeping, reporting, and PTD requirements in 40 CFR part 80, subpart N, which would be mandatory for producers of EFF and natural gasoline EFF blendstock. The proposed recordkeeping, reporting, and PTD requirements require only the specific information needed to determine compliance. All information submitted to the EPA pursuant to the recordkeeping and reporting requirements for which a claim of confidentiality is made is safeguarded according to the EPA policies set forth in 40 CFR part 2, subpart B.
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. The OMB control numbers for the EPA's regulations in 40 CFR are listed in 40 CFR part 9.
Submit your comments on the EPA's need for this information, the accuracy of the provided burden estimates and any suggested methods for minimizing respondent burden to the EPA using the docket identified at the beginning of this rule. You may also send your ICR-related comments to OMB's Office of Information and Regulatory Affairs via email to
I certify that this action will not have a significant economic impact on a substantial number of small entities under the RFA. In making this determination, the impact of concern is any significant adverse economic impact on small entities. An agency may certify that a rule will not have a significant economic impact on a substantial number of small entities if the rule relieves regulatory burden, has no net burden, or otherwise has a positive economic effect on the small entities subject to the rule. The small entities directly regulated by this proposed rule are primarily EFF refiners, biointermediate producers, and renewable fuel producers. To the extent small EFF refiners take advantage of the flexibilities provided by this action, it will only result in a cost savings. The requisite compliance requirements that go along with the proposed flexibilities will impose only minor costs in comparison to the savings; otherwise parties would not take advantage of the flexibility offered. Similarly, we do not believe that a small biointermediate producer or renewable fuel producer would choose to take advantage of the proposed program for biointermediates unless there was sufficient economic incentive for them to do so. Current small renewable fuel producers would not be compelled to use biointermediates, and as such, any costs associated with these provisions are purely voluntary. We do not anticipate that there will be any significant costs associated with the other proposed revisions to the RFS and other fuels programs. We have therefore concluded that this action will have no net regulatory burden for all directly regulated small entities.
This action does not contain any unfunded mandate as described in UMRA, 2 U.S.C. 1531-1538, and does
This action does not have federalism implications. It will not have substantial direct effects on the states, on the relationship between the national government and the states, or on the distribution of power and responsibilities among the various levels of government.
This action does not have tribal implications as specified in Executive Order 13175. This proposed rule will be implemented at the Federal level and affects transportation fuel refiners, blenders, marketers, distributors, importers, exporters, and renewable fuel producers and importers. Tribal governments would be affected only to the extent they produce, purchase, and use regulated fuels. Thus, Executive Order 13175 does not apply to this action.
The EPA interprets Executive Order 13045 as applying only to those regulatory actions that concern environmental health or safety risks that the EPA has reason to believe may disproportionately affect children, per the definition of “covered regulatory action” in section 2-202 of the Executive Order. This action is not subject to Executive Order 13045 because it implements specific standards established by Congress in statutes (CAA section 211(o)).
This action is not a “significant energy action” because it is not likely to have a significant adverse effect on the supply, distribution, or use of energy. This action provides a new/expanded market opportunity for natural gasoline, allows renewable fuel suppliers to take advantage of biointermediate feedstocks that might make fuel production more economical, and proposes various other revisions to the RFS program. There are no additional costs for sources in the energy supply, distribution, or use sectors.
This action involves technical standards. The EPA proposes to update a number of regulations that already contain voluntary consensus standards, practices, and specifications to more recent versions of these standards, and to propose the use of VCS for motor vehicle gasoline, EFF, natural gasoline EFF blendstock, butane, and pentane. In accordance with the requirements of 1 CFR 51.5, the EPA is proposing to incorporate by reference the use of ASTM test methods listed below in Table XI.I-1. A detailed discussion of these test methods can be found in sections IV.F.2, IX.A, and IX.C of this preamble. The standards may be obtained through the ASTM Web site (
This proposed rulemaking also involves environmental monitoring or measurement. Consistent with the EPA's PBMS approach, in this proposal we have decided to seek comment on to allow the use of any method that meets prescribed performance criteria for sulfur in pentane, as well as sulfur, benzene, aromatic content, distillation, RVP, and oxygenate content in EFF and natural gasoline EFF blendstock. The PBMS approach is intended to be more flexible and cost effective for the regulated community; it is also intended to encourage innovation in analytical technology and improved data quality. The EPA is proposing not to preclude the use of any one method, whether it constitutes a VCS or not, as long as it meets the performance criteria specified in this proposal.
The EPA believes the human health or environmental risk addressed by this action will not have potential disproportionately high and adverse human health or environmental effects on minority, low-income, or indigenous populations. This proposed rule does not affect the level of protection provided to human health or the environment by applicable air quality standards. This action does not relax the control measures on sources regulated by the fuel programs and RFS regulations and therefore will not cause emissions increases from these sources.
Fuel additives, Gasoline, Motor vehicle pollution, Penalties, Reporting and recordkeeping requirements.
Fuel additives, Gasoline, Imports, Incorporation by reference, Labeling, Motor vehicle pollution, Penalties, Reporting and recordkeeping requirements.
For the reasons set forth in the preamble, the EPA proposes to amend 40 CFR parts 79 and 80 as follows:
42 U.S.C. 7414, 7524, 7545 and 7601.
(a) * * *
(3) Motor vehicle gasoline, leaded, non-premium—motor vehicle gasoline that contains more than 0.05 gram of lead per gallon but is not sold as “premium.” The Act defines the term “motor vehicle” to mean any self-propelled vehicle designed for transporting persons or property on a street or highway. For purposes of this registration, however, gasoline specifically blended and marketed for motorcycles, flexible fuel vehicles as defined in 40 CFR 86.1803-01, or flexible fuel engines as defined in 40 CFR 1054.801, is excluded.
(f) * * *
(6) * * *
(iii) * * * The registrants' communications should be sent to the following address: Attn: Fuel/Additives Registration, U.S. Environmental Protection Agency, 1200 Pennsylvania Ave. NW., Mail Code 6405A, Washington, DC 20460.
(a) * * *
(1) * * * Forms for submitting this data may be obtained from EPA at the following address: Attn: Fuel/Additives Registration, U.S. Environmental Protection Agency, 1200 Pennsylvania Ave. NW., Mail Code 6405A, Washington, DC 20460.
42 U.S.C. 7414, 7521, 7542, 7545, and 7601(a).
The revisions and additions read as follows:
(h)
(l)
(p)
(q)
(r)
(t)
(aa)
(vvv)
(aaaa)
The sampling methods specified in this section shall be used to collect samples of gasoline, diesel fuel, blendstocks, fuel additives, ethanol flex fuel, natural gasoline ethanol flex fuel blendstock, and renewable fuels for purposes of determining compliance with the requirements of this part.
(a) For purposes of determining compliance with the fuel standards of 40 CFR part 80, a test result will be rounded to the nearest unit of significant digits specified in the applicable fuel standard in accordance with the rounding method described in ASTM E29-13, Standard Practice for Using Significant Digits in Test Data to Determine Conformance with Specifications, approved August 1, 2013.
(b) ASTM E29-13 is incorporated by reference. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. A copy may be obtained from the American Society for Testing and Materials, 100 Barr Harbor Dr., West Conshohocken, PA 19428-2959. Copies may be inspected at the Air Docket, EPA/DC, William Jefferson Clinton Building West, Room B102, 1301 Constitution Ave. NW., Washington, DC, or at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call (202) 741-6030 or go to:
(a) For submitting notifications, applications, petitions, or other communications with the EPA, use one of the following addresses for mailing:
(1) For U.S. Mail: Attn: [TITLE AS DIRECTED], U.S. Environmental Protection Agency, 1200 Pennsylvania Ave. NW., Mail Code 6405A, Washington, DC 20460
(2) For commercial service: Attn: [TITLE AS DIRECTED], U.S. Environmental Protection Agency, William Jefferson Clinton Building North, Mail Code 6405A, Room 6520V, 1200 Pennsylvania Ave. NW., Washington, DC 20004; Phone: 1-800-385-6164.
(b) [Reserved]
(b)
(e) * * *
(1) * * *
(i) Any person may request a testing exemption by submitting an application that includes all the information listed in paragraphs (e)(3) through (6) of this section to the attention of “Test Exemptions” to the address in § 80.10(a).
The revisions and additions read as follows:
(a)
(1)(i) Through December 31, 2015, the sulfur content of gasoline must be determined by ASTM D2622.
(ii) Beginning January 1, 2016, the sulfur content of gasoline must be determined by a test method approved under § 80.47.
(2)(i) Through December 31, 2015, the sulfur content of butane must be determined by ASTM D6667.
(ii) Beginning January 1, 2016, the sulfur content of butane must be determined by a test method approved under § 80.47.
(b)
(1) Through December 31, 2015, olefin content must be determined using ASTM D1319.
(2) Beginning January 1, 2016, olefin content must be determined by a test method approved under § 80.47.
(d)
(1) Through December 31, 2015, distillation parameters must be determined using ASTM D86.
(2) Beginning January 1, 2016, distillation parameters must be determined by a test method approved under § 80.47. (Note: The precision estimates for reproducibility in ASTM D86-12 do not apply; see § 80.47(h).)
(e)
(1) Through December 31, 2015, benzene content must be determined using ASTM D5769 or ASTM D3606, except that ASTM D3606 instrument parameters shall be adjusted to ensure complete resolution of the benzene, ethanol, and methanol peaks because ethanol and methanol may cause interference with ASTM D3606 when present.
(2) Beginning January 1, 2016, benzene content must be determined by a test method approved under § 80.47.
(f)
(1) Through December 31, 2015, aromatic content must be determined using ASTM D5769, except the sample chilling requirements in section 8 of this standard method are optional.
(2) Beginning January 1, 2016, aromatic content must be determined by a test method approved under § 80.47.
(g)
(1) Through December 31, 2015, oxygen and oxygenate content must be determined using ASTM D5599.
(2) Beginning January 1, 2016, oxygen and oxygenate content must be determined by a test method approved under § 80.47.
(h)
(2) Any refiner, importer, or oxygenate blender may determine benzene content in pentane using ASTM D6729 for purposes of meeting any testing requirement, provided that the test result is correlated with the method specified in paragraph (h)(1) of this section.
(i)
(2) Any refiner, importer, or oxygenate blender may determine aromatic content in pentane using ASTM D6729 for purposes of meeting any testing requirement, provided that the test result is correlated with the method specified in paragraph (i)(1) of this section.
(j)
(2) Any refiner, importer, or oxygenate blender may determine C6-plus hydrocarbon content in pentane using ASTM D6729 for purposes of meeting any testing requirement, provided that the test result is correlated with the method specified in paragraph (j)(1) of this section.
(k) * * *
(1)
(i) ASTM D86-12, Standard Test Method for Distillation of Petroleum Products at Atmospheric Pressure, approved December 1, 2012 (“ASTM D86”).
(ii) ASTM D1319-13, Standard Test Method for Hydrocarbon Types in Liquid Petroleum Products by Fluorescent Indicator Adsorption, approved May 1, 2013 (“ASTM D1319”).
(iii) ASTM D2622-10, Standard Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-ray Fluorescence Spectrometry, approved February 15, 2010 (“ASTM D2622”).
(iv) ASTM D3606-10, Standard Test Method for Determination of Benzene and Toluene in Finished Motor and Aviation Gasoline by Gas Chromatography, approved October 1, 2010 (“ASTM D3606”).
(v) ASTM D5191-13, Standard Test Method for Vapor Pressure of Petroleum Products (Mini Method), approved December 1, 2013 (“ASTM D5191”).
(vi) ASTM D5599-00 (Reapproved 2010), Standard Test Method for Determination of Oxygenates in Gasoline by Gas Chromatography and Oxygen Selective Flame Ionization Detection, approved October 1, 2010 (“ASTM D5599”).
(vii) ASTM D5769-10, Standard Test Method for Determination of Benzene, Toluene, and Total Aromatics in Finished Gasolines by Gas Chromatography/Mass Spectrometry, approved May 1, 2010 (“ASTM D5769”).
(viii) ASTM D6667-10, Standard Test Method for Determination of Total Volatile Sulfur in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, approved October 1, 2010 (“ASTM D6667”).
(ix) ASTM D6730-01 (Reapproved 2011), Standard Test Method for Determination of Individual Components in Spark Ignition Fuels by 100-Metre Capillary (Pre-Column) High-Resolution Gas Chromatography, approved May 1, 2011 (“ASTM D6730”).
(x) ASTM D6729-14, Standard Test Method for Determination of Individual Components in Spark Ignition Fuels by 100-Metre Capillary High-Resolution Gas Chromatography, approved October 1, 2014 (“ASTM D6729”).
The revisions and addition read as follows:
(b)
(2)
(i) The arithmetic average of a continuous series of at least 10 tests performed using good laboratory practices on a commercially available gravimetric sulfur standard in the range of 1-10 ppm shall not differ from the accepted reference value (ARV) of the standard by more than 0.47 ppm sulfur, where the accuracy criteria is 0.75*(1.5*r/2.77), where “r” is the repeatability (Example: 0.75*(1.5*1.15ppm/2.77) = 0.47 ppm);
(ii) The arithmetic average of a continuous series of at least 10 tests performed using good laboratory practices on a commercially available gravimetric sulfur standard in the range of 10-20 ppm shall not differ from the ARV of the standard by more than 0.94 ppm sulfur, where the accuracy criteria is 0.75*(1.5*r/2.77), where “r” is the repeatability (Example: 0.75*(1.5*2.30ppm/2.77) = 0.94 ppm); and
(iii) In applying the tests of paragraphs (b)(2)(i) and (ii) of this section, individual test results shall be compensated for any known chemical interferences using good laboratory practices.
(3) The test method specified at § 80.46(a)(1) is exempt from the requirements of paragraphs (b)(1) and (2) of this section.
(c) * * *
(2) * * *
(i) The arithmetic average of a continuous series of at least 10 tests performed using good laboratory practices on a commercially available gravimetric sulfur standard in the range of 1-10 ppm, say 10 ppm, shall not differ from the ARV of the standard by more than 0.47 ppm sulfur, where the accuracy criteria is 0.75*(1.5*r/2.77), where “r” is the repeatability (Example: 0.75*(1.5*1.15ppm/2.77) = 0.47 ppm);
(ii) The arithmetic average of a continuous series of at least 10 tests performed using good laboratory practices on a commercially available gravimetric sulfur standard in the range of 10-20 ppm, say 20 ppm, shall not differ from the ARV of the standard by more than 0.94 ppm sulfur, where the accuracy criteria is 0.75*(1.5*r/2.77), where “r” is the repeatability (Example: 0.75*(1.5*2.30ppm/2.77) = 0.94 ppm); and
(3) The test method specified at § 80.46(a)(2) is exempt from the requirements of paragraphs (c)(1) and (2) of this section.
(d) * * *
(2) The test method specified at § 80.46(b)(1) is exempt from the requirements of paragraph (d)(1) of this section.
(e) * * *
(2) The test method specified at § 80.46(f)(1) is exempt from the requirements of paragraph (e)(1) of this section.
(f) * * *
(2) The test method specified at § 80.46(g)(1) is exempt from the requirements of paragraph (f)(1) of this section.
(g) * * *
(2) The test method specified at § 80.46(c)(1) is exempt from the requirements of paragraph (g)(1) of this section.
(h) * * *
(2) The test method specified at § 80.46(d)(1) is exempt from the requirements of paragraph (h)(1) of this section.
(i) * * *
(2) The test methods specified at § 80.46(e)(1) are exempt from the requirements of paragraph (i)(1) of this section.
(j) * * *
(2) The test method specified at § 80.2(z) is exempt from the requirements of paragraph (j)(1) of this section.
(l) * * *
(2)(i) The test facility demonstrates that the test method meets the applicable precision information for the method-defined or non-VCSB absolute fuel parameter as described in this section.
(iii) For the non-VCSB absolute fuel parameter of sulfur in gasoline, butane, and pentane, the test facility shall include information demonstrating that the comparison of the non-VCSB test method and respective designated primary test method results in sample specific biases that are determined as random. If the sample specific biases through use of ASTM D6708 between the non-VCSB test method and designated primary test method cannot be determined as random, the non-VCSB test method is disqualified from approval.
(4) The test methods specified at §§ 80.2(z) and 80.46(a)(1), (a)(2), (b)(1), (c)(1), (d)(1), (e)(1), (f)(1), and (g)(1) are exempt from the requirements of paragraphs (l)(1) through (3) of this section.
(n) * * *
(1)(i)
(ii) The expanded uncertainty of the ARV of consensus named fuels shall be included in the following accuracy qualification criterion: Accuracy qualification criterion = square root [(0.75R)^2 + (0.75R)^2/L], where L = the number of single results obtained from different labs used to calculate the consensus ARV.
(2)(i)
(o) * * *
(1)(i)
(ii) The expanded uncertainty of the ARV of consensus named fuels shall be included in the following accuracy qualification criterion: Accuracy qualification criterion = square root [(0.75R)^2 + (0.75R)^2/L], where L = the number of single results obtained from different labs used to calculate the consensus ARV.
(2)(i)
(p) * * *
(1)(i)
(ii) The expanded uncertainty of the ARV of consensus named fuels shall be included in the following accuracy qualification criterion: Accuracy qualification criterion = square root [(0.75R)^2 + (0.75R)^2/L], where L = the number of single results obtained from different labs used to calculate the consensus ARV.
(2)(i)
(3)(i)
(a) * * *
(11) * * *
(viii) * * *
(C) The survey plan must be sent to the attention of “RFG Program (Survey Plan)” to the address in § 80.10(a);
(d) * * *
(4) For U.S. Postal delivery, the petition shall be sent to the attention of “RFG Program (Baseline Petition)” to the address in § 80.10(a).
(a) * * *
(2) The CPA or CIA shall provide a copy of the auditor's report to the EPA within the time specified in § 80.75(m).
(a) * * *
(5) Unless otherwise required by this section, finished test fuels must conform to the requirements for commercial gasoline described in ASTM D 4814-14b, Standard Specification for Automotive Spark-Ignition Engine Fuel, approved October 1, 2014, which is incorporated by reference. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be inspected at U.S. Environmental Protection Agency, William Jefferson Clinton Building West, Room B102, 1301 Constitution Ave. NW., Washington, DC 20460, or at the National Archives and Records Administration (NARA). * * *
(c) * * *
(9) * * *
(v) In all such instances, a curing VAR must be created and maintained, which documents the use of the appropriate equation as specified above, and otherwise complies with the requirements of § 80.170(f)(7).
(f) * * *
(4) For all detergent blending facilities, a record specifying, for each VAR period, the total volume in gallons of unadditized base gasoline used to produce ethanol flex fuel pursuant to the requirements of subpart N of this part;
(d)
(b) Other detergent registration and certification data, and certain other information which may be specified in this subpart, shall be sent to the attention of “Detergent Additive Certification” to the address in § 80.10(a).
(c) Notifications to EPA regarding program exemptions, detergent dilution and commingling, and certain other information which may be specified in this subpart, shall be sent to the attention of “Detergent Enforcement Program” to the address in § 80.10(a).
(d) * * *
(1) * * *
(i) ASTM D4806-15, Standard Specification for Denatured Fuel Ethanol for Blending with Gasolines for Use as Automotive Spark-Ignition Engine Fuel, approved April 1, 2015.
(ii) ASTM D4814-14b, Standard Specification for Automotive Spark-Ignition Engine Fuel, approved October 1, 2014.
(b) Applications for small refiner status must be sent to the attention of “Gasoline Sulfur Program (Small Refiner)” to the address in § 80.10(a).
(b) The sulfur baseline request must be sent to the attention of “Gasoline Sulfur Program (Sulfur Baseline)” to the address in § 80.10(a).
(b) The baseline must be sent to the attention of “Nonroad Rule Diesel Fuel Baseline” to the address in § 80.10(a).
(b) Alternative labels to those specified in paragraph (a) of this section may be used as approved by EPA. Send requests to the attention of “ECA Marine Fuel Alternative Label Request” to the address in § 80.10(a).
The addition and revision read as follows:
(b) * * *
(4) Provide information indicating that a comparison of the non-VCSB test method and its respective designated primary test method results in sample specific biases that are determined to be random. If the sample specific biases through use of ASTM D6708 between the non-VCSB test method and designated primary test method cannot be determined as random, the non-VCSB test method is disqualified from approval.
(d) * * *
(4) The approval of any test method under paragraph (b) of this section shall be valid from the date of approval from the Administrator.
(b) The volume baseline must be sent via certified mail with return receipt or express mail with return receipt to the attention of “Diesel Baseline” to the address in § 80.10(a).
(a)
(c) * * *
(2)
(a) * * *
(6) Beginning February 1, 2018, a refiner that produces E15 at a blender pump-refinery, as defined in § 80.1500, shall be deemed in compliance with the provisions of this subpart, provided the refiner is in compliance with the requirements for gasoline produced by blender pump-refiners in § 80.1530.
(a) * * *
(1)(i) * * *
OC = Benzene credits used by the refinery or importer to show compliance (gallons benzene).
(b) For U.S. Postal delivery, the benzene baseline application shall be sent to the attention of “MSAT2 Benzene” to the address in § 80.10(a).
(b) Applications for small refiner status must be sent to the attention of “MSAT2 Benzene” to the address in § 80.10(a).
The revisions and additions read as follows:
(1) It is derived from renewable biomass.
(2) It does not meet the definition of renewable fuel and RINs were not generated for it as a renewable fuel in its own right.
(3) It is produced at a facility registered with EPA that is different than the facility at which it is used to produce renewable fuel.
(4) It is made from the feedstock and will be used to produce the renewable fuel in accordance with the process(es) listed in the approved pathway (as described in Table 1 to § 80.1426 or a pathway approval pursuant to § 80.1416) that the biointermediate producer and renewable fuel producer are using to convert renewable biomass to renewable fuel.
(5)(i) It is substantially altered from the feedstock listed in the approved pathway that the biointermediate producer and renewable fuel producer are using to convert renewable biomass to renewable fuel;
(ii) The substantial alteration is other than a form change such as chopping, crushing, grinding, pelletizing, filtering, compacting/compression, centrifuging, dewatering/drying, melting, or the addition of water to produce a slurry; and
(iii) The substantial alteration does not involve the isolation or concentration of non-characteristic components of the feedstock to yield an intermediate product not contemplated by EPA in establishing the approved pathway that the biointermediate producer and the renewable fuel producer are using to convert renewable biomass to renewable fuel.
(1)(i) Is a transportation fuel, transportation fuel additive, heating oil, or jet fuel.
(ii) Meets the definition of either biodiesel or non-ester renewable diesel.
(iii) Is registered as a motor vehicle fuel or fuel additive under 40 CFR part 79, if the fuel or fuel additive is intended for use in a motor vehicle.
(2) Cellulosic diesel includes heating oil and jet fuel made from cellulosic feedstocks and renewable fuel that is co-processed with petroleum.
(1) For facilities that commenced construction prior to December 19, 2007, the exempted baseline peak capacity is based on the last five calendar years prior to 2008, unless no such production exists, in which case actual peak capacity is based on any calendar year after startup during the first three years of operation.
(2) For facilities that commenced construction after December 19, 2007, and before January 1, 2010, that are fired with natural gas, biomass, or a combination thereof, the exempted baseline peak capacity is based on any calendar year after startup during the first three years of operation.
(2) A fuel oil that is used to heat or cool interior spaces of homes or buildings to control ambient climate for human comfort. The fuel oil must be liquid at 60 degrees Fahrenheit and 1 atmosphere of pressure, and contain no more than 2.5% mass solids.
(1) Non-viscous renewable diesel satisfies all of the following:
(i) Is not a mono-alkyl ester.
(ii) Meets the ASTM D975-13a (incorporated by reference, see § 80.1468) Grade No. 1-D or No. 2-D specifications prior to blending with any other product.
(iii) Can be used in an engine designed to operate on conventional diesel fuel.
(iv) Is produced through a hydrotreating process.
(2) Viscous renewable diesel (VRD) satisfies all of the following:
(i) Is not a mono-alkyl ester.
(ii) Is a straight vegetable oil
(iii) Is intended for use as one of the following:
(A) A blend in an engine designed to operate on conventional diesel fuel (referred to as VRD for blending or VRD-B).
(B) A neat fuel for use either: In a vehicle or engine that has been converted to use such fuel under an EPA-approved Clean Alternative Fuel Conversion under 40 CFR part 85, subpart F; as heating oil; or as jet fuel (collectively referred to as VRD for neat use or VRD-N).
(2) Ethanol covered by this definition shall be denatured using an ethanol denaturant as required in 27 CFR parts 19 through 21. Any volume of ethanol denaturant added to the undenatured ethanol by a producer or importer in excess of 2 volume percent shall not be included in the volume of ethanol for purposes of determining compliance with the requirements under this subpart.
(1) Soy bean oil.
(2) Oil from annual covercrops.
(3) Algal oil.
(4) Biogenic waste oils/fats/greases that are of plant origin.
(5) Non-food grade corn oil.
(6)
(7) Canola/Rapeseed Oil.
(8) Any other vegetable oil listed as a feedstock in Table 1 to § 80.1426 or described in a pathway approved pursuant to § 80.1416.
(1) Sales records for planted trees or tree residue together with other written documentation connecting the land in question to these purchases;
(2) Purchasing records for seeds, seedlings, or other nursery stock together with other written documentation connecting the land in question to these purchases;
(3) A written management plan for silvicultural purposes;
(4) Documentation of participation in a silvicultural program sponsored by a Federal, state or local government agency;
(5) Documentation of land management in accordance with an agricultural or silvicultural product certification program;
(6) An agreement for land management consultation with a professional forester that identifies the land in question;
(7) Evidence of the existence and ongoing maintenance of a road system or other physical infrastructure designed and maintained for logging use, together with one of the above-mentioned documents; or
(8) Records satisfying the requirements of paragraph (2) of the definition of existing agricultural land in this section that demonstrates that the land was actively managed or fallow agricultural land.
(g) Fuel produced by a facility meeting the requirements of paragraphs (c) or (d) of this section is not a qualifying renewable fuel unless it meets one of the following requirements:
(1) It is made in one facility from feedstock that is renewable biomass.
(2) It is made from a feedstock that is derived from renewable biomass and is listed in Table 1 to § 80.1426.
(3) It is made from a feedstock that is renewable biomass that was pre-processed at another facility, and such pre-processing at that facility was limited to form changes such as chopping, crushing, grinding, pelletizing, filtering, compaction/compression, centrifuging, dewater/drying, melting, and/or the addition of water to produce a slurry.
(c) * * *
(4) Applications for equivalence values must be sent to the attention of “RFS2 Program (Equivalence Value Application)” to the address in § 80.10(a).
(g) * * *
(5) D has the value of 7 to denote fuel categorized as cellulosic biomass-based diesel.
The revisions and additions read as follows:
(a) * * *
(1) To the extent permitted under paragraphs (b) and (c) of this section, producers and importers of renewable fuel (other than VRD-B) and VRD blenders must generate RINs to represent that fuel if all of the following occur:
(2) To generate RINs for imported renewable fuel, including any renewable fuel contained in imported transportation fuel, heating oil, or jet fuel, importers must obtain information from a non-RIN-generating foreign renewable fuel producer that is registered pursuant to § 80.1450 sufficient to make the appropriate determination regarding the applicable D code and compliance with the renewable biomass definition for each imported batch for which RINs are generated.
(4) Where a feedstock or biointermediate is used to produce renewable fuel is not entirely renewable biomass, RINs may only be generated for the portion of fuel that is derived from renewable biomass, as calculated under paragraph (f)(4) of this section.
(c) * * *
(4) Importers shall not generate RINs for renewable fuel imported from a non-RIN-generating foreign renewable fuel producer unless the foreign renewable fuel producer is registered with EPA as required in § 80.1450.
(5) Importers shall not generate RINs for renewable fuel that has already been assigned RINs by a RIN-generating foreign renewable fuel producer.
(8) RINs shall not be generated for the production of a biointermediate.
(9) Parties shall not generate RINs to represent renewable fuel prior to EPA approval of applicable registration requirements under § 80.1450(b), (c), (d)(1), and (d)(4).
(e) * * *
(1) Except as provided in paragraph (g) of this section for delayed RINs, the producer or importer of renewable fuel (other than VRD-B) or the VRD blender must assign all RINs generated to volumes of renewable fuel.
(f) * * *
(1)
(ii) In choosing an appropriate D code, producers and importers may disregard any incidental, de minimis feedstock contaminants that are impractical to remove and are related to customary feedstock production and transport.
(iii) Tables 1 and 2 to this section do not apply to, and impose no requirements with respect to, volumes of fuel for which RINs are generated pursuant to paragraph (f)(6) of this section.
(iv) Pathways in Table 1 to this section and advanced technologies in Table 2 to this section also apply in cases wherein the renewable fuel producer is using a biointermediate as the feedstock.
(v) For the purposes of identifying the appropriate pathway in Table 1 of this section, biointermediates used as feedstocks for the production of renewable fuel are considered to be equivalent to the renewable biomass from which they were derived, with the following exceptions:
(A) Oil that is physically separated from any woody or herbaceous biomass and used to produce cellulosic biofuel shall not generate D-code 3 or 7 RINs.
(B) Sugar or starch that is physically separated from cellulosic biomass and used to produce cellulosic biofuel shall not generate D-code 3 or 7 RINs.
(C) Free fatty acids that are physically separated from mono-, bi-, and triglycerides in biogenic waste oils/fats/greases are not biogenic waste oils/fats/greases.
(vi) If a renewable fuel producer uses a biointermediate as the feedstock for
(3) * * *
(v) * * *
V
EV
(vi) * * *
V
(4)
(i) * * *
(A) * * *
(
FE
FE
(iv) In no case shall the RIN volume V
(v) In determining the RIN volume V
(17) * * *
(ii) In addition to the requirements specified in paragraph (f)(17)(i) of this section, VRD-N producers may generate RINs for such fuel only in accordance with § 80.1479(a).
(18)
(19)
(i) Renewable fuel producers can only generate RINs if the lifecycle greenhouse gas emissions are below the threshold value for the applicable pathway when calculated by a method approved by EPA as part of a petition pursuant to § 80.1416.
(ii) Renewable fuel producers cannot generate RINs in a given calendar year after the applicable submittal date for the annual GHG report specified in 40 CFR 98.3 unless the renewable fuel producer has received verification that the geologic sequestration facility has satisfied all applicable reporting obligations pursuant to 40 CFR part 98, subpart RR.
(iii) If EPA is notified of a surface leak, the producer shall not generate RINs using a CCS pathway until the remediation plan submitted under § 80.1474(g) has been approved by EPA and the renewable fuel producer takes appropriate corrective action, if necessary.
(iv) Renewable fuel producers shall notify EPA if a participating geologic sequestration facility has filed a request for discontinuation under 40 CFR 98.441.
(v) Renewable fuel producers must meet all of the following conditions (in addition to any other applicable requirements):
(A) Registration requirements under § 80.1450(b)(1)(xvi).
(B) Reporting requirements under § 80.1451(b)(1)(ii)(W).
(C) Recordkeeping requirements under § 80.1454(b)(11).
(a) * * *
(3) * * *
(ii) A cellulosic biomass-based diesel RIN with a D code of 7 cannot be used to demonstrate compliance with both a cellulosic biofuel RVO and a biomass-based diesel RVO.
(d)
(2) In fulfillment of its RVOs, each party is subject to the provisions of paragraphs (a)(2), (a)(3), (a)(6), and (a)(8) of this section.
(3) No more than 20 percent of the RVO calculated according to a formula at § 80.1433(a) may be fulfilled using RINs generated in the year prior to the year in which the RVO was incurred.
(b) * * *
(11) Any party that must retire RINs for redesignated neat or blended renewable fuel under § 80.1433 must separate any RINs that have been assigned to the redesignated volume.
(c) If the exporter knows or has reason to know that a volume of exported renewable fuel is cellulosic biomass-based diesel, he must treat the exported volume as either cellulosic biofuel or biomass-based diesel when determining his Renewable Volume Obligations pursuant to paragraph (b) of this section.
(a) * * *
(3) In the event that EPA determines that some portion of RINs generated for a batch of renewable fuel produced using a biointermediate are invalid, then all RINs generated for that batch of renewable fuel are deemed invalid, unless EPA in its sole discretion determines that some portion of these RINs are valid.
(a) A party that received fuel containing any amount of renewable fuel, ethanol, butanol, biodiesel, renewable diesel, naptha, or other biomass-derived fuel, and who knows or has reason to know that a party to whom it is transferring the fuel intends a use other than as transportation fuel, heating oil, jet fuel, or fuel for a stationary internal combustion engine, must include a statement on a product transfer document it delivers to the fuel transferee at the time of fuel transfer designating the fuel for other uses, as specified in paragraph (e) of this section, and must retire an appropriate number and type of RINs according to one of the following equations, as appropriate, depending on fuel volume and type, and in accordance with paragraphs (a)(1) through (a)(4) of this section. However, this paragraph and paragraphs (b) through (d) of this
(1) Except as provided in paragraph (a)(5) of this section,
(2) Except as provided in (a)(5),
(3)
(4)
(5) If the party knows or has reason to know that the fuel would qualify as cellulosic biomass-based diesel if it was designated for use as transportation fuel, heating oil, jet fuel, or fuel for a stationary internal combustion engine, it must choose either the formula specified in paragraph (a)(1) of this section or that in paragraph (a)(2) of this section to calculate the number and type of RINs that must be retired.
(b) For the purposes of calculating the number of RINs that must be retired under paragraphs (a) of this section:
(1) If the renewable fuel category and equivalence value for the discrete volume k can be determined based on its composition, then the appropriate formula and equivalence value based on such information shall be used in the calculation pursuant to paragraph (a).
(2) If the discrete volume k is known to be biomass-based diesel but the composition is unknown, the EV
(3) If neither the renewable fuel category nor EV
(c) VOL
(1) Information from the supplier of the blend of the concentration of fuel originally produced as renewable fuel in the blend.
(2) Determination of the renewable portion of the blend using Method B or Method C of ASTM D 6866 (incorporated by reference, see § 80.1468), or an alternative test method as approved by the EPA.
(3) Assuming the maximum concentration of the renewable fuel in the blend as allowed by law.
(d) All RIN retirements required pursuant paragraph (a) of this section shall be identified in EMTS within thirty (30) business days of the transfer of the fuel designated for use in an application other than as transportation fuel, heating oil, jet fuel, or fuel for a stationary internal combustion engine.
(e) A party that received fuel containing any amount of renewable fuel, ethanol, butanol, biodiesel, renewable diesel, naptha, or other biomass-derived fuel, and who knows or has reason to know that a party to whom it is transferring the fuel intends a use other than as transportation fuel, heating oil, jet fuel, or fuel for a stationary internal combustion engine must include a statement on a product transfer document it delivers to the fuel transferee at the time of fuel transfer that includes the following information:
(1) “This volume of fuel is designated and intended for use other than as transportation fuel, heating oil, jet fuel, or fuel for a stationary internal combustion engine.”;
(2) “To the extent necessary, the appropriate number and type of RINs have been retired pursuant to 40 CFR 80.1433.”;
(3) Date of RIN retirement in EMTS; and
(4) EMTS Transaction ID for the transaction in which the appropriate number and type of RINs were retired.
(f) Any volume of fuel which is designated for use in an application other than as transportation fuel, heating oil, jet fuel, or fuel for a stationary internal combustion engine cannot be redesignated as renewable fuel.
(a) A RIN must be retired in any of the following cases:
(1)
(2)
(3)
(4)
(5)
(6)
(7)
(i) If the equivalence value for the spilled or disposed of volume may be determined pursuant to § 80.1415 based on its composition, then the appropriate equivalence value shall be used.
(ii) If the equivalence value for a spilled or disposed volume of renewable fuel cannot be determined, the equivalence value shall be 1.0.
(iii) If the owner of a volume of renewable fuel that is spilled or disposed of and reported establishes that no RINs were generated to represent the volume, then no gallon-RINs shall be retired.
(8)
(i) If the equivalence value for the contaminated or spoiled volume may be determined pursuant to § 80.1415 based on its composition, then the appropriate equivalence value shall be used.
(ii) If the equivalence value for a contaminated or spoiled volume of renewable fuel cannot be determined, the equivalence value shall be 1.0.
(iii) If the owner of a volume of renewable fuel that is contaminated or spoiled and reported establishes that no RINs were generated to represent the volume, then no gallon-RINs shall be retired.
(9)
(10)
(11)
(12)
(13)
(b) In the case that retirement of a RIN is necessary, the following provisions apply:
(1) Any party affected by such retirement must keep copies and adjust its records, reports, and compliance calculations in which the retired RIN was used.
(2) The retired RIN must be reported in the applicable reports under § 80.1451.
(3) The retired RIN must be reported in the EPA Moderated Transaction System pursuant to § 80.1452(c).
(4) Where the importer of renewable fuel is required to retire RINs under paragraph (a)(6) of this section, the importer must report the retired RINs in the applicable reports under §§ 80.1451, 80.1466(k), and 80.1466(m).
(a)(1) Renewable fuel blenders who handle and blend less than 250,000 gallons of renewable fuel per year, and who do not have one or more reported or unreported Renewable Volume Obligations, are permitted to delegate their RIN-related responsibilities to the party directly upstream of them who supplied the renewable fuel for blending.
(2) Renewable fuel blenders who handle and blend renewable fuel for parties that have a national security exemption under 40 CFR part 80, or a national security exemption under paragraph (f) of this section, and who do not have one or more reported or unreported Renewable Volume Obligations, are permitted to delegate their RIN-related responsibilities to the party directly upstream of them who supplied the renewable fuel for blending.
(f)
(i) Tactical military vehicles, engines, or equipment having an EPA national security exemption from emission standards under 40 CFR 85.1708, 89.908, 92.908, 94.908, 1042.635, or 1068.225.
(ii) Tactical military vehicles, engines, or equipment that are not subject to a national security exemption from vehicle or engine emissions standards as described in paragraph (f)(1)(i) of this section but, for national security purposes (for purposes of readiness for deployment overseas), need to be fueled on the same transportation fuel, heating oil, or jet fuel as the vehicles, engines,
(e) * * *
(2) * * *
(iv)(A) The following information related to petitions submitted under this section that have been accepted by EPA for evaluation is not entitled to confidential treatment under 40 CFR part 2, subpart B:
(
(
(
(
(B) The following information related to EPA determinations on petitions submitted under this section is not entitled to confidential treatment under 40 CFR part 2, subpart B:
(
(
(
(
(
(C) The EPA will disclose the information specified in paragraphs (e)(2)(iv)(A) and (B) of this section on its Web site, or will otherwise make it available to interested parties, notwithstanding any claims that the information is entitled to confidential treatment under 40 CFR part 2, subpart B.
(h) Verification letters under paragraph (b) of this section, petitions for small refinery hardship extensions under paragraph (e) of this section, and small refinery exemption waiver notices under paragraph (f) of this section shall be sent to the attention of “RFS Program” to the address in § 80.10(a).
(h) * * *
(6)(i) The following information related to petitions submitted under this section that have been accepted by EPA for evaluation is not entitled to confidential treatment under 40 CFR part 2, subpart B:
(
(
(
(
(ii) The following information related to EPA determinations on petitions submitted under this section is not entitled to confidential treatment under 40 CFR part 2, subpart B:
(
(
(
(
(
(iii) The EPA will disclose the information specified in paragraphs (h)(6)(i) and (ii) of this section on its Web site, or will otherwise make it available to interested parties, notwithstanding any claims that the information is entitled to confidential treatment under 40 CFR part 2, subpart B.
(i) Small refiner status verification letters, small refiner exemption waivers, or applications for extensions of the small refiner temporary exemption under this section must be sent to the attention of “RFS Program” to the address in § 80.10(a).
(d) * * *
(2) A petition submitted under this section should be sent to the attention of “RFS Program” to the address in § 80.10(a).
(d) Production outlook reports shall be sent to the attention of “RFS Program (Production Output Reports)” to the address in § 80.10(a).
The revisions and additions read as follows:
(a)
(b)
(1) A description of the types of renewable fuels, ethanol, or biointermediate(s) that the producer intends to produce at the facility and that the facility is capable of producing without significant modifications to the existing facility. For each type of renewable fuel, ethanol, or biointermediate(s) the renewable fuel producer or foreign ethanol producer shall also provide all the following:
(i)(A) A list of all the feedstocks and/or biointermediates the facility intends to utilize without significant modification to the existing facility.
(B) A description of the type(s) of renewable biomass that will be used as feedstock material to produce the biointermediate, if applicable.
(C) A list of the EPA company registration numbers and EPA facility registration numbers of all biointermediate producers and biointermediate production facilities that will supply biointermediates for renewable fuel or ethanol production, as appropriate.
(D) An affidavit from or contract with the biointermediate producer stating its intent to supply biointermediate to the renewable fuel producer, and certifying the renewable and non-renewable components of the biointermediate that it intends to provide to the renewable fuel producer.
(ii) A description of the facility's renewable fuel, ethanol, or biointermediate production processes, including:
(A) A process diagram with all relevant unit processes labeled, including required inputs and outputs at each step and current operating pressures and temperatures of each unit.
(B) A description of the renewable biomass or ethanol treatment process, including required inputs and outputs used at each step.
(C) A description of the mechanical, chemical, and biochemical mechanisms by which renewable biomass is processed prior to being converted to renewable fuel, ethanol, or a biointermediate.
(D) Determination of the throughput rate-limiting step in the production process and corresponding capacity of the production process.
(E) For a producer of renewable fuel seeking to generate RINs with different D codes from the same batch or co-processing renewable biomass and non-renewable biomass:
(
(
(
(
(F) For registrations indicating production of cellulosic biofuel (D codes 3 or 7) from feedstocks other than biogas (including through pathways in rows K, L, M, and N of Table 1 to § 80.1426), the producer must demonstrate the ability to convert cellulosic components of feedstock into fuel by providing all of the following:
(
(
(
(G) For registrations indicating the production of any biointermediate, the biointermediate producer must provide all of the following:
(
(
(
(
(
(
(
(iv) * * *
(A) * * *
(
(
(v) For renewable fuel producers, the following records that support the facility's baseline volume and exempted baseline volume, as applicable, as defined in § 80.1401 or, for foreign ethanol facilities, their production volume:
(A) For all facilities, copies of the most recent applicable air permits issued by the U.S. Environmental Protection Agency, state, local air pollution control agencies, or foreign governmental agencies and that govern the construction and/or operation of the renewable fuel or foreign ethanol facility.
(C) * * *
(
(vii)(A) For a producer of renewable fuel, a foreign producer of ethanol, or a biointermediate producer producing a biointermediate made from separated yard waste per § 80.1426(f)(5)(i)(A):
(
(
(B) For a producer of renewable fuel, a foreign producer of ethanol, or a biointermediate producer producing a biointermediate made from separated food waste per § 80.1426(f)(5)(i)(B) or from biogenic waste oils/fats/greases:
(
(
(viii) For a producer of renewable fuel, a foreign producer of ethanol, or biointermediate producer of a biointermediate made from separated municipal solid waste per § 80.1426(f)(5)(i)(C):
(A) The location of the municipal waste establishment(s) from which the separated municipal solid waste is collected or from which material is collected that will be processed to produce separated municipal solid waste.
(B) A plan providing ongoing verification that there is separation of recyclable paper, cardboard, plastics, rubber, textiles, metals, and glass wastes to the extent reasonably practicable and which documents the following:
(
(
(
(C) Contracts relevant to materials recycled from municipal waste streams as described in § 80.1426(f)(5)(iii).
(D) Certification by the producer that recycling is conducted in a manner consistent with goals and requirements of applicable State and local laws relating to recycling and waste management.
(ix) * * *
(A) For a producer of ethanol from grain sorghum or a foreign ethanol producer making product from grain sorghum and seeking to have it sold as renewable fuel after addition of ethanol denaturant, provide a plan that has been submitted and accepted by U.S. EPA that includes the following information:
(xi) * * *
(A) An affidavit from the producer of the fuel oil meeting paragraph (2) of the definition of heating oil in § 80.1401 stating that the fuel oil for which RINs have been generated will be sold for the purposes of heating or cooling interior spaces of homes or buildings to control ambient climate for human comfort, and no other purpose.
(B) Affidavits from the final end user or users of the fuel oil stating that the fuel oil meeting paragraph (2) of the definition of heating oil in § 80.1401 is being used or will be used for purposes of heating or cooling interior spaces of homes or buildings to control ambient climate for human comfort, and no other purpose, and acknowledging that any other use of the fuel oil would violate EPA regulations and subject the user to civil and/or criminal penalties under the Clean Air Act.
(xv) For a producer of cellulosic biofuel made from crop residue, a foreign ethanol fuel producer from crop residue and seeking to have it sold after denaturing as cellulosic biofuel, or a biointermediate producer producing a biointermediate for use in the production of a cellulosic biofuel made from crop residue, provide all the following information:
(xvi) For a producer of renewable fuel that achieves the greenhouse gas reductions necessary to qualify for a renewable fuel pathway by using CCS:
(A) A CCS plan that includes each of the following:
(
(
(
(
(
(
(
(
(
(
(B) A description of the CO
(C) If a producer of renewable fuel that achieves the greenhouse gas reductions necessary to qualify for a renewable fuel pathway by using CCS changes the geologic sequestration facility or if the participating geologic sequestration facility ends sequestration operations, the renewable producer shall update their registration under paragraph (d)(1) of this section.
(D) Any additional information EPA may request, as appropriate.
(xvii) For a producer of renewable fuel that is produced by co-processing renewable biomass and non-renewable feedstocks simultaneously to produce a fuel that is partially renewable:
(A) A description of how the renewable content of the partial renewable fuel will be determined after co-processing.
(B) The method the producer will use to calculate the number of gallon-RINs on a per-batch basis as described in § 80.1426(f)(4).
(C) Any additional information EPA may request, as appropriate.
(xviii) For a producer of cellulosic biofuel made from short-rotation willow or short-rotation hybrid poplar:
(A) A list of all the species and hybrids the producer intends to utilize as short-rotation willow or short-rotation hybrid poplar.
(B) A written justification that explains why each feedstock a producer lists according to paragraph (b)(1)(xviii)(A) of this section meets the definition of “short-rotation willow” or “short-rotation hybrid poplar” per § 80.1401.
(C) Records demonstrating that the short-rotation willow or short-rotation hybrid poplar feedstocks will only be sourced from locations that qualify as a tree plantation as defined in § 80.1401, including documentation that the land was cleared prior to December 19, 2007, and actively managed on December 19, 2007.
(D) Contracts and affidavits from the party or parties supplying the producer with short-rotation willow or short-rotation hybrid poplar that the feedstocks supplied to the producer shall be grown only at locations that qualify as a tree plantation and for which records required pursuant to paragraph (b)(1)(xviii)(C) of this section have been provided to the producer.
(xix) For VRD-N producers, submit all relevant information in § 80.1426(f)(17) and the following:
(A) Letters of approval from EPA for a Clean Alternative Fuel Conversion under 40 CFR part 85, subpart F, for all intended transferees of VRD-N.
(B) Copies of contracts with the intended fuel transferee, or affidavits signed by a responsible officer of the intended transferee, together with other documentation that EPA may specify on a case-by-case basis that demonstrate that the contracted end users have converted vehicles and engines under an EPA-approved Clean Alternative Fuel Conversion under 40 CFR part 85, subpart F.
(xx) A responsible corporate officer, or an official in an equivalent position, of the renewable fuel producer, foreign ethanol producer, or biointermediate producer in submitting its registration materials to EPA under this section, must include, sign, and date the following certification: “I certify under penalty of law that the attached registration materials were developed, received, reviewed, and responded to under my direction or supervision by qualified personnel in accordance with the requirements of 40 CFR part 80. Based on my personal knowledge and experience, or inquiry of personnel involved in developing the registration materials, the information submitted herein is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fines and imprisonment for knowing violations.”
(xxi) For each facility, the renewable fuel producer, foreign ethanol producer, or biointermediate producer shall make the following information readily accessible on the facility's publicly-available Web site (if such Web site exists) as a public notification:
(A) The name of the independent third-party engineer that conducted the engineering review under paragraph (b)(2) of this section.
(B) A summary of how the independent third-party engineer meets the competency and independent criteria.
(C) The independent third-party engineer's and producer's signed certification statements as required under paragraphs (b)(1)(xx) and (b)(2)(iii) of this section.
(2)
(i) The engineering review and written report required under this section must be conducted by a professional engineer, as specified in paragraph (b)(2)(i)(A) or (B) of this section, as applicable, who is an independent third-party engineer. The verifying independent third-party engineer must be:
(A) For a domestic renewable fuel production facility or a domestic biointermediate production facility: A professional engineer who is licensed by an appropriate state agency in the United States and trained or certified in proper verification techniques, with professional work experience in the chemical engineering field or related to renewable fuel production.
(B) For a foreign renewable fuel production facility, a foreign ethanol production facility, or a foreign biointermediate production facility: An engineer who is a foreign equivalent to a professional engineer licensed in the United States and trained or certified in proper auditing techniques, with professional work experience in the chemical engineering field or related to renewable fuel production.
(ii) The independent third-party engineer and its contractors and subcontractors must be registered with EPA and meet all applicable requirements under paragraph (h) of this section.
(iii) The independent third-party engineer shall sign, date, and submit to EPA with the written report the following conflict of interest statement: “I certify that the engineering review and written report required and submitted under 40 CFR 80.1450(b)(2) was conducted and prepared by me, or under my direction or supervision, in accordance with a system designed to assure that qualified personnel properly gather and evaluate the information
(iv)(A) To verify the accuracy of the information provided in paragraph (b)(1)(ii) of this section, the independent third-party engineer shall conduct independent calculations of the throughput rate-limiting step in the production process, take digital photographs with date and geographic coordinates stamps of all process units depicted in the process flow diagram during the site visit, and certify that all process unit connections are in place and functioning based on the site visit.
(B) To verify the accuracy of the information in paragraph (b)(1)(iii) of this section, the independent third-party engineer shall obtain independent documentation from parties in contracts with the producer for any co-product sales or disposals.
(C) To verify the accuracy of the information provided in paragraph (b)(1)(iv) of this section, the independent third-party engineer shall obtain independent documentation from all process heat fuel suppliers of the process heat fuel supplied to the facility.
(D) To verify the accuracy of the information provided in paragraph (b)(1)(v) of this section, the independent third-party engineer shall conduct independent calculations of the Converted Fraction that will be used to generate RINs.
(vi) The renewable fuel producer, foreign ethanol producer, or biointermediate producer must retain records of the review and verification, as required in § 80.1454(b)(6) or (n)(4), as applicable.
(ix) The independent third-party engineer must provide to EPA documentation demonstrating that a site visit, as described in paragraph (b)(2) of this section, occurred. Such documentation shall include digital photographs with date and geographic coordinates stamps of the process units taken during the site visit and a description of what is depicted in the photographs.
(x) Reports required under paragraph (b)(2) of this section shall be electronically submitted directly to EPA by an independent third-party engineer using forms and procedures established by EPA.
(d)
(B) Any biointermediate producer who makes changes to their biointermediate production facility that will allow them to produce a biointermediate for use in the production of a renewable fuel that is not reflected in the biointermediate producer's registration information on file with EPA must update their registration information and submit a copy of an updated independent third-party engineering review on file with EPA at least 60 days prior to producing the new biointermediate for use in the production of the renewable fuel.
(ii) The producer may also submit an addendum to the independent third-party engineering review on file with EPA provided the addendum meets all the requirements in paragraph (b)(2) of this section and verifies for EPA the most up-to-date information at the producer's existing facility.
(2)(i) Any producer of renewable fuel or any foreign ethanol producer who makes any other changes to a facility that will affect the producer's registration information but will not affect the renewable fuel category for which the producer is registered per paragraph (b) of this section must update his registration information 7 days prior to the change.
(ii)(A) Any biointermediate producer who makes any other changes to a biointermediate production facility that will affect the biointermediate producer's registration must update their registration information 7 days prior to the change.
(B) All biointermediate producers must update their registration information on file with EPA at least 60 days prior to transferring any biointermediate for use in the production of a renewable fuel produced by a renewable fuel producer not contained in their registration information on file with EPA.
(3) All producers of renewable fuel, foreign ethanol producers, and biointermediate producers must update registration information and submit an updated independent third-party engineering review according to the schedule in paragraph (d)(3)(i) or (ii) of this section, and including the information specified in paragraph (d)(3)(iii) or (iv) of this section, as applicable:
(i) For all producers of renewable fuel and foreign ethanol producers registered in calendar year 2010, the updated registration information and independent third-party engineering review shall be submitted to EPA by January 31, 2013, and by January 31 of every third calendar year thereafter; or
(ii) For all producers of renewable fuel, foreign ethanol producers, and biointermediate producers registered in any calendar year after 2010, the updated registration information and independent third-party engineering review shall be submitted to EPA by January 31 of every third calendar year after the first year of registration.
(iii) For all producers of renewable fuel and foreign ethanol producers, in addition to conducting the engineering review and written report and verification required by paragraph (b)(2) of this section, the updated independent third-party engineering review shall include a detailed review of the renewable fuel producer's calculations used to determine VRIN of a representative sample of batches of each type of renewable fuel produced since the last registration. The representative sample shall be selected in accordance with the sample size guidelines set forth at § 80.127.
(iv) For biointermediate producers, in addition to conducting the engineering review and written report and verification required by paragraph (b)(2) of this section, the updated independent third-party engineering review shall include a detailed review of the biointermediate producer's calculations used to determine the renewable biomass and cellulosic renewable biomass proportions, as required to be reported to EPA under § 80.1451(i)(2), of a representative sample of batches of each type of biointermediate produced since the last registration. The representative sample shall be selected in accordance with the sample size guidelines set forth at § 80.127.
(v) Renewable fuel producers claiming an exemption specified in
(4)
(ii) Producers of renewable fuel that purchase, acquire, or otherwise obtain a facility that has been operational within the previous six months and was previously registered to a different renewable fuel producer under paragraph (b) of this section, must meet the following requirements:
(A) The following information must be provided to EPA:
(
(
(
(
(B) The documents and information described in paragraphs (b)(4)(ii)(A)(
(C) The document(s) described in paragraph (b)(4)(ii)(A)(
(iii) The renewable fuel producer that is acquiring the previously registered facility under paragraph (d)(4)(ii) of this section shall not generate RINs under § 80.1426 until EPA accepts all applicable registration information.
(iv) For renewable fuel producers that have been approved by EPA to transfer ownership of a facility under paragraph (d)(4)(ii) of this section, those parties may, at EPA's sole discretion, be allowed to retroactively generate RINs pursuant to § 80.1426(f) and assign those RINs to batches of renewable fuel pursuant to § 80.1452(e) back to the effective date of the transfer of ownership for the facility, if EPA determines that the renewable fuel producer met all applicable requirements under paragraphs (b) and (d) of this section for the facility at the effective date of the transfer of ownership for the facility.
(v) The previous renewable fuel producer that owned the facility shall not generate RINs pursuant to § 80.1426 or assign RINs to a batch of renewable fuel for a facility pursuant to § 80.1452(b) on or after the effective date of the transfer of ownership for the facility.
(vi) For purposes of this section, the effective date of the transfer of ownership for a facility shall be the date that the renewable fuel producer that is acquiring the previously registered facility purchased the facility, took custody of the facility, or began operating the facility, whichever is later.
(f)(1) Except as provided in paragraph (f)(2) of this section, all documents required for a new registration of any facility claiming an exemption under § 80.1403(c) or (d), and all documents required to support requests by registered facilities to amend registrations to increase the baseline volume of fuel qualifying for an exemption under § 80.1403(c) or (d), must be received by EPA no later than November 16, 2016.
(2) Paragraph (f)(1) of this section does not limit the ability of a renewable fuel producer to newly register with EPA as a result of the transfer of ownership of a facility that was previously registered to another renewable fuel producer, provided that such producer shall be subject to the same limitations as the previous owner regarding the baseline volume for which an exemption under § 80.1403(c) or (d) apply.
(g) * * *
(9)
(ii) Any independent third-party auditor who makes any changes other than those specified in paragraphs (g)(9)(i), (iii), and (iv) of this section that will affect the third-party auditor's registration information must update its registration information 7 days prior to the change.
(iii) Independent third-party auditors must update their QAPs at least 60 days prior to verifying RINs generated by a renewable fuel facility for a pathway not covered in the independent third-party auditor's QAPs.
(iv) Independent third-party auditors must update their QAPs at least 60 days prior to verifying RINs generated by any renewable fuel facility not identified in the independent third-party auditor's existing registration.
(11) * * *
(i) The Administrator may issue a notice of intent to revoke the registration of a third-party auditor if the Administrator determines that the auditor has failed to fulfill any requirement of this subpart, including, but not limited to, the failure to fulfill QAP services. The notice of intent shall include an explanation of the reasons for the proposed revocation.
(h)
(1) Documentation, as described in paragraph (b)(2)(i)(A) and (B) of this section, for every professional engineer who will provide a third-party engineering review.
(2) Documentation of the independent third-party engineer's training or certification in proper verification techniques, with professional work experience in the chemical engineering field or related to renewable fuel production.
(3) Documentation demonstrating that every independent third-party engineer who conducts an independent third-party engineering review pursuant to paragraph (b)(2) or (d)(1) of this section is, as required, maintaining professional liability insurance, as defined in 31 CFR 50.5(q). Independent third-party engineers shall use insurance providers
(4) Documentation of the name, address, company, and facility identification numbers of all renewable fuel producers, foreign ethanol producers, and biointermediate producers that the independent third-party engineer intends to conduct an independent third-party engineering review for under paragraph (b)(2) or (d)(1) of this section during the current calendar year.
(5) An affidavit, or electronic consent, from each domestic renewable fuel producer and biointermediate producer stating its intent to have the independent third-party engineer conduct an independent third-party engineering review of any of the renewable fuel producer, foreign ethanol producer, or biointermediate producer's facilities during the current calendar year.
(6) An affidavit stating that the independent third-party engineer, its affiliates, contractors, and subcontractors are independent of the renewable fuel producer, foreign ethanol producer, or biointermediate producer. For an independent third-party engineer or its affiliates, contractors, or subcontractors to be considered independent under this section, all of the following conditions must be met:
(i) The independent third-party engineer shall act impartially when performing all activities under this section.
(ii) The independent third-party engineer shall not be owned or operated by the renewable fuel producer, foreign ethanol producer, or biointermediate producer, or any subsidiary or employee of these producers.
(iii) The independent third-party engineer shall not be owned or operated by an obligated party or any subsidiary or employee of an obligated party as defined in § 80.1406.
(iv) The independent third-party engineer shall not have conducted research, development, design, construction, or consulting for the renewable fuel producer, foreign ethanol producer, or biointermediate producer within the last three years. For purposes of this requirement, consulting does not include performing or participating in the engineering review (including the verification activities) pursuant to this section.
(v) The independent third-party engineer shall not provide other business or consulting services to any renewable fuel producer, foreign ethanol producer, or biointermediate producer, including advice or assistance to implement the findings or recommendations of the written report described in paragraph (b)(2) of this section, for a period of at least three years following submission of the final written report.
(vi) The independent third-party engineer shall ensure that all personnel involved in the engineering review activities under this section do not accept employment with the owner or operator of the renewable fuel producer, foreign ethanol producer, or biointermediate producer for a period of at least three years following submission of the final written report. For the purposes of this requirement, employment does not include performing or participating in the engineering review activities pursuant to paragraph (b)(2) of this section.
(vii) The independent third-party engineer shall have written policies and procedures to ensure that the independent third-party engineer and all personnel under the independent third-party engineer's direction or supervision comply with the competency, independence, and impartiality requirements of this section.
(viii) For engineering review services as described in paragraph (b)(2) of this section provided to a biointermediate producer, the independent third-party engineer shall not be owned or operated by any renewable fuel producer listed in paragraph (b)(1)(xv) of this section and the independent third-party engineer shall be free from any interest in any renewable fuel producer listed in paragraph (b)(1)(xv) of this section. Any renewable fuel producer listed in paragraph (b)(1)(xv) of this section shall be free from any interest in the independent third-party engineer's business.
(ix) The independent third-party engineer shall not perform an attest engagement under § 80.1464 for the renewable fuel producer, foreign ethanol producer, or biointermediate producer within three years of the date that the independent third-party engineer conducted the independent third-party engineering review at that same facility pursuant to paragraph (b)(2) or (d)(1) of this section.
(x) The independent third-party engineer shall not be a QAP auditor, as described in § 80.1471, or perform QAP audits, as described in § 80.1472, for the renewable fuel producer, foreign ethanol producer, or biointermediate producer in which it performed an independent third-party engineering review pursuant to paragraph (b)(2) or (d)(1) of this section.
(xi) The independent third-party engineer shall not own, buy, sell, or otherwise trade RINs.
(xii) The independent third-party engineer shall be free from any interest or the appearance of any interest in the renewable fuel producer, foreign ethanol producer, or biointermediate producer's business and receive no financial benefit from the outcome of the registration, apart from receipt of payment for the independent third-party engineering review services under paragraph (b)(2) of this section.
(xiii) The renewable fuel producer, foreign ethanol producer, or biointermediate producer shall be free from any interest or the appearance of any interest in the independent third-party engineer's business.
(xiv) The independent third-party engineer must not be debarred, suspended, or proposed for debarment pursuant to the Government-wide Debarment and Suspension regulations, 40 CFR part 32, or the Debarment, Suspension and Ineligibility provisions of the Federal Acquisition Regulations, 48 CFR part 9, subpart 9.4.
(7) Documentation with the name and contact information for each person employed, affiliated with, or under contract or subcontract, by the independent third-party engineer to conduct independent third-party engineering reviews.
(8) Documentation of the independent third-party engineer's written policies and procedures to ensure that the independent third-party engineer and all affiliates, contractors, and subcontractors under the professional engineer's direction or supervision comply with the competency, independence, and impartiality requirements of this section.
(9) The independent third-party engineer shall sign, date, and submit to EPA with the registration the following conflict of interest statement: “I certify under penalty of law that the registration materials submitted to EPA were developed, received, reviewed, and responded to under my direction or supervision by qualified personnel in accordance with the requirements of 40 CFR part 80. Based on my personal knowledge and experience, or inquiry of personnel involved in developing the registration materials, the information submitted herein is true, accurate, and complete. I am aware that there are
(10)
(11)
(ii) Within 60 days of receipt of the notice of intent to revoke, the independent third-party engineer may submit written comments concerning the notice, including, but not limited to, a demonstration of compliance with the requirements that provide the basis for the proposed revocation. The Administrator shall review and consider any such submission before taking final action concerning the proposed revocation.
(iii) If the independent third-party engineer fails to respond in writing, within 60 days, to the notice of intent to revoke, the revocation shall become final by operation of law and the Administrator shall notify the independent third-party engineer of such revocation.
(i)
(i) The company has reported no activity in EMTS for twenty-four consecutive months.
(ii) The company, third-party auditor, or independent third-party engineer has failed to comply with the registration requirements of this section.
(iii) The company, third-party auditor, or independent third-party engineer has failed to submit any required notification or report within 30 days of the required submission date under this subpart.
(iv) Any attest engagement required under § 80.1464 has not been received within 30 days of the required submission date.
(v) The company, third-party auditor, or independent third-party engineer fails to pay a penalty or to perform any requirements under the terms of a court order, administrative order, consent decree, or administrative settlement between the company and EPA.
(vi) The company, third-party auditor, or independent third-party engineer submits false or incomplete information.
(vii) The company, third-party auditor, or independent third-party engineer denies EPA access or prevents EPA from completing authorized activities under sections 114 or 208 of the Clean Air Act despite presenting a warrant or court order. This includes a failure to provide reasonable assistance.
(vii) The company, third-party auditor, or independent third-party engineer fails to keep or provide the records required in this section.
(ix) The company, third-party auditor, or independent third-party engineer otherwise circumvents the intent of the Clean Air Act or of this subpart.
(x) If a company has registered a facility using CCS technology pursuant to § 80.1450(b)(xvi) and there is an occurrence of surface leakage of any CO
(2) Except as provided in paragraph (i)(3) of this section, EPA will use the following process whenever it decides to deactivate the registration of a company, third-party auditor, or independent third-party engineer:
(i) EPA will provide written notification to the responsible corporate officer identifying the reasons or deficiencies of why EPA intends to deactivate the company's registration. The company will have fourteen calendar days from the date of the notification to correct the deficiencies identified or explain why there is no need for corrective action.
(ii) If the basis for EPA's notice of intent to deactivate registration is the absence of EMTS activity, a stated intent to engage in activity reported through EMTS will be sufficient to avoid deactivation of registration.
(iii) If the company does not respond, does not correct identified deficiencies, or does not provide an adequate explanation regarding why such correction is not necessary within the time allotted for response, EPA may deactivate the company's registration without further notice to the party.
(3) In instances of willfulness or those in which public health, interest, or safety requires otherwise, EPA may deactivate the registration of the company, third-party auditor, or independent third-party engineer without any notice to the party. EPA will provide written notification to the responsible corporate officer identifying the reasons EPA deactivated the registration of the company, third-party auditor, or independent third-party engineer.
(4) Impact of registration deactivation:
(i) A company whose registration is deactivated shall still be liable for violation of any requirements of this subpart.
(ii) A company whose registration is deactivated will not be listed on any public list of actively registered companies that is maintained by EPA.
(iii) A company whose registration is deactivated will not have access to any of the electronic reporting systems associated with the renewable fuel standard program, including the EPA Moderated Transaction System (EMTS).
(iv) A company whose registration is deactivated must submit any corrections of deficiencies to EPA on forms, and following policies, established by EPA.
(v) If a company, third-party auditor, or independent third-party engineer whose registration has been deactivated wishes to re-register, they may seek to do so by submitting a new registration pursuant to the requirements in paragraphs (a) through (c), (e), and (g) of this section, as applicable.
The revisions and additions read as follows:
(a)
(1) * * *
(v) Beginning with the 2017 compliance year and every year thereafter, the production volume and import volume for each of the products listed in § 80.1407(c) and (e) for the reporting year.
(vi) Beginning with the 2017 calendar year and every year thereafter, the volume of renewable fuel blended into gasoline or diesel fuel as described in § 80.1407(b) and (d) for the reporting year.
(vii) Beginning with the 2017 calendar year and every year thereafter, the production volume and import volume for heating oil, as defined in § 80.2(ccc). Volumes of renewable heating oil for which RINs were generated under § 80.1426 shall not be included.
(viii) The combined total production volume and import volume as calculated in § 80.1407(b) and (d) for the reporting year.
(ix) The RVOs, as defined in § 80.1427(a) for obligated parties, § 80.1430(b) for exporters of renewable fuel, and § 80.1433(a) for parties that must retire RINs under § 80.1433, for the reporting year.
(xi) The total current-year RINs by category of renewable fuel, as those fuels are defined in § 80.1401 (
(xix) The total current-year RINs by category of renewable fuel, as those fuels are defined in § 80.1401 (
(b)
(1) * * *
(ii) * * *
(D) The importer EPA facility registration number and foreign renewable fuel producer company registration number, if applicable.
(I) The volume of ethanol denaturant and applicable equivalence value of each batch.
(K) The types and quantities of feedstocks and biointermediates used.
(L) The process(es), feedstock(s), and biointermediate(s) used and proportion of renewable volume attributable to each process and feedstock.
(W) Renewable fuel producers that achieve the greenhouse gas reductions necessary to qualify for a renewable fuel pathway by using CCS as part of the renewable fuel production process shall report to EPA in accordance with the applicable requirements of 40 CFR part 98, subpart PP, and shall also meet the following requirements:
(
(
(
(
(g) * * *
(1) * * *
(ii) * * *
(D) The importer EPA facility registration number and foreign renewable fuel producer company registration number, if applicable.
(I) The volume of ethanol denaturant and applicable equivalence value of each verified batch.
(2) * * *
(vii) A list of all facilities including the EPA's company and facility registration numbers audited under an approved quality assurance plan under § 80.1469, the date the independent third-party auditor conducted the on-site visit and audit, the name(s) of the professional engineer(s) that conducted or oversaw the on-site visit and audit, and whether the facility has a remote monitoring system.
(i)
(1) Beginning on the effective date of the final rule, biointermediate batch production reports for each biointermediate production facility shall be submitted according to the schedule specified in paragraph (f)(2) of this section.
(2) The biointermediate batch production reports shall include all the following information for each batch of biointermediate produced or imported, where “batch” means a discrete quantity of biointermediate produced or imported and assigned a unique batch number per § 80.1475(h):
(i) The biointermediate producer's name.
(ii) The biointermediate producer's EPA company registration number.
(iii) The biointermediate producer's EPA facility registration number.
(iv) The applicable reporting period.
(v) The production date and batch number of each batch.
(vi) The adjusted cellulosic content of each batch, as defined in § 80.1401, and certification that the cellulosic content of each batch was derived from cellulose, hemicellulose, or lignin that was derived from renewable biomass, as defined in § 80.1401.
(vii) The volume of each batch produced.
(viii) The types and quantities of feedstocks used.
(ix) The renewable fuel type(s) each batch of biointermediate was designated to be used as a feedstock material for.
(x) The EPA company registration number and EPA facility registration number for each renewable fuel producer or foreign renewable fuel producer that received title to each batch.
(xi) The percentage of each batch of biointermediate that met the definition of renewable feedstock and certification that this portion of the batch of biointermediate was derived from renewable biomass, as defined in § 80.1401.
(xii) The process(es) and feedstock(s) used and proportion of biointermediate volume attributable to each process and feedstock.
(xiii) The type of co-products produced with each batch.
(xiv) The quantity of co-products produced in each quarter.
(xv) Any additional information the Administrator may require.
(j) The following tables set forth EPA determinations regarding the extent to which listed data elements from reports submitted pursuant to this section are eligible for treatment as confidential business information.
The revisions and additions read as follows:
(b) * * *
(11) The volume of ethanol denaturant and applicable equivalence value of each batch.
(16) Starting January 1, 2018, or a later date designated by EPA, the type and quantity of biointermediate(s) used for the batch, if applicable.
(17) Starting January 1, 2018, or a later date designated by EPA, the EPA facility registration number of each biointermediate production facility at which a biointermediate used for the batch was produced, if applicable.
(d) Parties shall not assign RINs to a batch of renewable fuel pursuant to paragraph (b) of this section prior to EPA approval of applicable registration requirements under § 80.1450(b), (c), (d)(1), and (d)(4).
(e) The following tables set forth EPA determinations regarding the extent to which listed EMTS data elements are eligible for treatment as confidential business information.
(f) EPA's public release of EPA enforcement-related determinations and EPA actions under the RFS program, together with basic information regarding the party or parties involved and the RINs in question, does not involve the release of information that is entitled to treatment as confidential business information. Such information may include the company name and company identification number of the party that generated the RINs in question, the facility name and facility identification number of the facility at which the fuel associated with the RINs in question was allegedly produced or imported, the total quantity of RINs in question, the time period when the RINs in question were generated, and the batch number(s) and the D code(s) of the RINs in question. Enforcement-related determinations and actions within the scope of this rule include EPA determinations that RINs are invalid under § 80.1474(b)(4)(i)(C)(2) and (b)(4)(ii)(C)(2), notices of violation, administrative complaints, civil complaints, criminal informations and criminal indictments.
(a) On each occasion when any person transfers ownership of neat and/or blended renewable fuels or separated RINs subject to this subpart, other than when fuel is sold or dispensed at a retail outlet or wholesale purchaser-consumer facility, the transferor shall provide to the transferee documents that include the following information, as applicable.
(12) Except as provided in § 80.1433(e), an accurate and clear statement on the product transfer document of the fuel type and intended fuel use or uses, from the options listed below, which is made in good faith:
(d) For fuel oil meeting paragraph (2) of the definition of heating oil in § 80.1401, the PTD of the fuel oil shall state: “This volume of renewable fuel oil is designated and intended to be used to heat or cool interior spaces of homes or buildings to control ambient climate for human comfort. Do NOT use for process heat or cooling or any other purpose, as these uses are prohibited pursuant to 40 CFR 80.1460(g).”
(e) On each occasion when any party transfers title or custody of a biointermediate, the transferor must provide to the transferee documents that include all of the following information:
(1) The name and address of the transferor and transferee.
(2) The transferor's and transferee's EPA company registration and applicable facility registration numbers.
(3) The volume of biointermediate that is being transferred.
(4) The date of the transfer.
(5) The location of the biointermediate at the time of the transfer.
(6) The renewable fuel type the biointermediate was designated to be used as a feedstock material for by the biointermediate producer under § 80.1475(i).
(7) The composition of the biointermediate being transferred, including:
(i) The type and quantity of each feedstock, specified exactly as described in Table 1 to § 80.1426, that was used to make the biointermediate.
(ii) The percentage of each feedstock that is renewable biomass, rounded to two decimal places.
(iii) For a biointermediate that contains both renewable and non-renewable feedstocks:
(A) The percentage of each feedstock that is not renewable biomass, rounded to two decimal places.
(B) The feedstock energy from the renewable biomass used to make the biointermediate, in Btu.
(C) The feedstock energy from the non-renewable biomass used to make the biointermediate, in Btu.
(D) The total percentage of the biointermediate that may generate RINs, rounded to two decimal places.
(E) The total percentage of the biointermediate that may not generate RINs, rounded to two decimal places.
(iv) For a biointermediate that contains cellulosic material:
(A) The percentage of each feedstock in § 80.1453(e)(6)(ii) that is cellulosic, rounded to two decimal places.
(B) The percentage of each feedstock in § 80.1453(e)(6)(ii) that is non-cellulosic, rounded to two decimal places, if applicable.
(C) The total percentage of the biointermediate that may generate cellulosic RINs, rounded to two decimal places.
(D) For separated municipal solid waste as described in § 80.1426(f)(5)(i)(C), the cellulosic portion of the biointermediate is equivalent to the biogenic portion.
(E) For separated food waste, the non-cellulosic percentage is assumed to be zero percent unless it is demonstrated to be partially cellulosic.
(F) For separated yard waste, as described in § 80.1426(f)(5)(i)(A), 100% of separated yard waste is deemed to be cellulosic.
(G) The following statement “I certify that the cellulosic content of this feedstock was derived from cellulose, hemicellulose, or lignin that was derived from renewable biomass.”
(v) The type and proportion of RINs that may be generated for the biointermediate.
(8) Copies of records specified in §§ 80.1454(n)(3) and 80.1454(n)(5) through (7) for the volume being transferred, as applicable.
(9) The following statement designating the volume of biointermediate as feedstock for the production of a renewable fuel: “This volume is designated and intended for use as biointermediate feedstock in the production of renewable fuel as defined in 40 CFR 80.1401. Parties shall not generate RINs on this feedstock material.”
The revisions and additions read as follows:
(a)
(4) * * *
(i) Methods and variables used to calculate the Renewable Volume Obligations pursuant to § 80.1407, § 80.1430, or § 80.1433.
(7) For parties that must retire RINs under § 80.1433, invoices, bills of lading, and other documents describing the renewable fuel and the intended use of the renewable fuel for which RINs must be retired under § 80.1433.
(b) * * *
(3) * * *
(vii) Type and quantity of biointermediate used.
(6) Copies of registration documents required under § 80.1450, including information on fuels and products, feedstocks, biointermediates, facility production processes, process changes, and capacity, energy sources, and a copy of the independent third party engineering review written report submitted to EPA per § 80.1450(b)(2).
(11) For any producer of renewable fuel that achieves the greenhouse gas reductions necessary to qualify for a renewable fuel pathway by using CCS technology as part of the renewable fuel production process, records presenting accurate calculations verifying compliance with the applicable lifecycle greenhouse gas reductions reported in accordance with § 80.1451(b)(1)(ii)(W).
(d) * * *
(2) Domestic producers of renewable fuel made from qualified planted trees or tree residue from actively managed tree plantations must keep records that serve as evidence that the land from which the feedstock was obtained was cleared prior to December 19, 2007, and actively managed on December 19, 2007. The records must be provided by the feedstock producer and must include at least one of the following documents, which must be traceable to the land in question:
(vi) An agreement for land management consultation with a professional forester that identifies the land in question.
(viii) Records satisfying the requirements of paragraph (d)(3)(i) of this section that serve as evidence that the land on which the tree plantation is located was cleared or cultivated prior to December 19, 2007, and actively managed or fallow on December 19, 2007.
(h) * * *
(6) * * *
(iii) The survey plan must be sent to the attention of “RFS Program” to the address in § 80.10(a).
(n)
(1) Product transfer documents consistent with § 80.1453(e) and associated with the biointermediate producer's activities, if any, as transferor or transferee of biointermediates.
(2) Copies of all reports submitted to EPA under § 80.1451(i).
(3) Records related to the production of biointermediates for each biointermediate production facility, including all of the following:
(i) Batch volume.
(ii) Batch number.
(iii) Type and quantity of co-products produced.
(iv) Type and quantity of feedstocks used.
(v) Type and quantity of fuel used for process heat.
(vi) Feedstock energy calculations per § 80.1426(f)(4), as applicable.
(vii) Date of production.
(viii) Results of any laboratory analysis of batch chemical composition or physical properties.
(4) Copies of registration documents required under § 80.1450, including information on products, feedstocks, facility production processes, process changes, and capacity, energy sources, and a copy of the independent third party engineering review submitted to EPA per § 80.1450(b)(2)(i).
(5) Records demonstrating that feedstocks are renewable biomass, as required under paragraphs (d), (g), or (h) of this section.
(6) A biointermediate producer that produces a biointermediate from separated yard and food waste for use in the production of a renewable fuel, as described in § 80.1426(f)(5)(i)(A) and (B), or from separated municipal solid waste, as described in § 80.1426(f)(5)(i)(C), shall keep all records described in paragraph (j) of this section, as applicable.
(7) For any biointermediate made from
(8) Records, including contracts, related to the implementation of a QAP under § 80.1469.
(o) A producer of renewable fuel that achieves the greenhouse gas reductions necessary to qualify for a renewable fuel pathway by using CCS technology as part of the renewable fuel production process must retain records of all information reported in accordance with the applicable requirements of 40 CFR part 98, subpart PP, must follow the applicable record retention requirements specified by 40 CFR part 98, subpart PP, and one of the following, as applicable:
(1) If the injection occurs onsite, follow the record retention requirements specified by 40 CFR part 98, subpart RR, and retain records of all information reported by the producer or importer in accordance with the requirements of 40 CFR part 98, subpart RR.
(2) If the injection occurs offsite, retain records of all information reported by the facility or facilities that report in accordance with the requirements of 40 CFR part 98, subpart RR.
(p) Producers of renewable fuel using short-rotation willow or short-rotation hybrid poplar shall keep records of all of the following:
(1) The specific short-rotation willow or short-rotation hybrid poplar species or hybrids utilized to produce each batch of renewable fuel.
(2) The total quantity of each specific short-rotation willow or short-rotation hybrid poplar feedstock used for each batch.
(3) Total amount of fuel produced under the short-rotation willow or short-rotation hybrid poplar pathway for each batch.
(4) Affidavits from the short-rotation willow or short-rotation hybrid poplar feedstock suppliers confirming that the feedstocks supplied to the producer are grown only at locations that qualify as a tree plantation and for which records required pursuant to § 80.1450(b)(1)(xviii)(C) have been provided to the producer. The producer shall obtain affidavits under this paragraph at least once per calendar quarter.
(5) Contracts from the short-rotation willow or short-rotation hybrid poplar feedstock suppliers confirming that the feedstocks supplied to the producer are grown only at locations that qualify as a tree plantation and for which records required pursuant to § 80.1450(b)(1)(xviii)(C) have been provided to the producer.
(q) The records required under paragraphs (a) through (d) and (f) through (p) of this section and under § 80.1453 shall be kept for five years from the date they were created, except that records related to transactions involving RINs shall be kept for five years from the date of the RIN transaction.
(t) The records required in paragraphs (b)(3) and (c)(1) of this section must be transferred with any renewable fuel sent to the importer of that renewable fuel by any non-RIN-generating foreign producer.
The revisions and additions read as follows:
(b) * * *
(5) Introduce into commerce any renewable fuel produced from a feedstock, a biointermediate feedstock, or through a process that is not described in the person's registration information.
(c) * * *
(2) Use a RIN for compliance or transfer a RIN that was assigned to renewable fuel received by a person if the person uses the volume of fuel associated with the RIN for an application other than as transportation fuel, jet fuel, or heating oil.
(g)
(j)
(k)
(1) Fail to identify any incorrect information submitted by the renewable fuel producer, foreign ethanol producer, or biointermediate producer as described in § 80.1450(b)(2).
(2) Fail to meet any requirement related to engineering reviews as described in § 80.1450(b)(2).
(3) Fail to disclose to EPA any financial, professional, business, or other interests with parties for whom the independent third-party engineer provides services under § 80.1450.
(4) Fail to meet any requirement related to the independent third-party engineering review registration requirements in § 80.1450(b)(2) or (d)(1).
(l)
(a)
(2) Any person who causes another person to violate a prohibition under § 80.1460(a) through (d) or § 80.1460(g) through (l) is liable for a violation of § 80.1460(e).
(c)
(e)
(1) Each biointermediate producer, biointermediate importer, renewable fuel producer, renewable fuel importer, or foreign ethanol producer who owns, leases, operates, controls, or supervises the facility where the violation is found.
(2) Each biointermediate producer, biointermediate importer, renewable fuel producer, renewable fuel importer, or foreign ethanol producer who manufactured, imported, sold, offered for sale, dispensed, offered for supply, stored, transported, or caused the transportation of any biointermediate that is in the storage tank containing the biointermediate found to be in violation.
(3) Each carrier who dispensed, supplied, stored, or transported any biointermediate that was in the storage tank containing the biointermediate found to be in violation, provided that EPA demonstrates, by reasonably specific showings using direct or circumstantial evidence, that the carrier caused the violation.
The revisions and additions read as follows:
(a)
(1) * * *
(i) * * *
(A) The obligated party's volume of all products listed in § 80.1407(c) and (e), the exporter's volume of each category of exported renewable fuel identified in § 80.1430(b)(1) through (b)(4), or the volume of each category of renewable fuel identified in § 80.1433(a)(1) through (a)(4), as applicable.
(ii) Obtain documentation of any volumes of renewable fuel used in products listed in § 80.1407(c) and (e) at the refinery or import facility, exported during the reporting year, or redesignated as described in § 80.1433; compute and report as a finding the total volumes of renewable fuel represented in these documents.
(v) Compute and report as a finding the RVOs for the obligated party, exporter, or party that must retire RINs under § 80.1433, and any deficit RVOs carried over from the previous year or carried into the subsequent year, and verify that the values agree with the values reported to EPA.
(vii) For parties that must retire RINs under § 80.1433, perform all of the following:
(A) Obtain the database, spreadsheet, or other documentation that the party maintains for all renewable fuel for which RINs must be retired under § 80.1433.
(B) Compare the volume of products identified in these documents with the volumes reported to EPA.
(C) Verify that the volumes reported to EPA agree with the volumes identified in the database, spreadsheet, or other documentation, and report as a finding any exception.
(D) Select sample batches in accordance with the guidelines in § 80.127 from each separate category of renewable fuel identified in § 80.1451(a); obtain invoices, bills of lading, and other documentation for the representative samples; state whether any of these documents refer to the renewable fuel as advanced biofuel or cellulosic biofuel; and report as a finding whether or not the party calculated an advanced biofuel or cellulosic biofuel RVO for these fuels pursuant to § 80.1433(a)(1) or § 80.1433(a)(3).
(b) * * *
(1) * * *
(ii) Obtain production data for each renewable fuel batch by type of renewable fuel that was produced or imported during the year being reviewed; compute the RIN numbers, production dates, types, volumes of ethanol denaturant and applicable equivalence values, and production volumes for each batch; report the total RINs generated during the year being reviewed; and state whether this information agrees with the party's reports to EPA. Report as a finding any exceptions.
(v)(A) Obtain documentation, as required under § 80.1451(b), (d), and (e), associated with feedstock and biointermediate purchases for a representative sample, selected in accordance with the guidelines in § 80.127, of renewable fuel batches produced or imported during the year being reviewed.
(B) Verify that feedstocks were properly identified in the reports and met the definition of renewable biomass in § 80.1401.
(C) Verify that biointermediates were properly identified in the reports, if applicable.
(h)
(1)
(ii) Obtain any database, spreadsheet, or other documentation used to generate the information in the biointermediate production reports; compare the corresponding entries in the database or spreadsheet and report as a finding any discrepancies.
(iii) For a representative sample of biointermediate batches, selected in accordance with the guidelines in § 80.127, obtain records required under § 80.1454(n); compare these records to the corresponding batch entries in the reports procured in paragraph (h)(1)(i) of this section and report as a finding any discrepancies.
(2)
(ii) Review and verify the written verification and records generated as
(3)
(ii) Verify that the product transfer documents obtained in paragraph (h)(3)(i) of this section contain the applicable information required under § 80.1453 and report as a finding any product transfer document that does not contain the required information.
(iii) Verify the accuracy of the information contained in the product transfer documents reviewed pursuant to paragraph (h)(3)(ii) of this section with the records obtained and reviewed under paragraph (h)(1)(iii) of this section and report as a finding any exceptions.
The revisions and addition read as follows:
(a)
(b)
(c)
(d) * * *
(1) * * *
(iii) Obtain the EPA-assigned registration number of the RIN-generating foreign producer.
(v) Determine the date and time the vessel departs the port serving the RIN-generating foreign producer.
(vi) * * *
(B) That the RFS-FRRF remained segregated from Non-RFS-FRRF and other RFS-FRRF produced by a different foreign producer.
(3) * * *
(ii) Be independent under the criteria specified in § 80.65(f)(2)(iii); and
(e) * * *
(2) * * *
(ii) Where the port of entry volume is the lesser of the two volumes in paragraph (e)(1)(i) of this section, the importer shall calculate the difference between the number of RINs originally assigned by the RIN-generating foreign producer and the number of RINs calculated under § 80.1426 for the volume of renewable fuel as measured at the port of entry, and acquire and retire that amount of RINs in accordance with paragraph (k)(3) of this section.
(f)
(1) Any EPA inspector or auditor must be given full, complete, and immediate access to conduct inspections and audits of the foreign renewable fuel producer facility.
(ii) * * *
(C) Renewable fuel is stored or transported between the foreign renewable producer and the United States, including storage tanks, vessels and pipelines.
(v) * * *
(A) The volume of renewable fuel.
(C) Transfers of title or custody to the renewable fuel.
(vii) Any employee of the foreign renewable fuel producer must be made available for interview by the EPA inspector or auditor, on request, within a reasonable time period.
(2) An agent for service of process located in the District of Columbia shall be named, and service on this agent constitutes service on the foreign renewable fuel producer or any employee of the foreign renewable fuel producer for any action by EPA or otherwise by the United States related to the requirements of this subpart.
(3) The forum for any civil or criminal enforcement action related to the provisions of this section for violations of the Clean Air Act or regulations promulgated thereunder shall be governed by the Clean Air Act, including the EPA administrative forum where allowed under the Clean Air Act.
(4) United States substantive and procedural laws shall apply to any civil or criminal enforcement action against the foreign renewable fuel producer or any employee of the foreign renewable fuel producer related to the provisions of this section.
(5) Applying to be an approved foreign renewable fuel producer under this section, or producing or exporting renewable fuel under such approval, and all other actions to comply with the requirements of this subpart relating to such approval constitute actions or activities covered by and within the meaning of the provisions of 28 U.S.C. 1605(a)(2), but solely with respect to actions instituted against the foreign renewable fuel producer, its agents and employees in any court or other tribunal in the United States for conduct that violates the requirements applicable to the foreign renewable fuel producer under this subpart, including conduct that violates the False Statements Accountability Act of 1996 (18 U.S.C. 1001) and section 113(c)(2) of the Clean Air Act (42 U.S.C. 7413).
(6) The foreign renewable fuel producer, or its agents or employees, will not seek to detain or to impose civil or criminal remedies against EPA inspectors or auditors for actions performed within the scope of EPA employment or contract related to the provisions of this section.
(7) The commitment required by this paragraph shall be signed by the owner
(8) In any case where renewable fuel produced at a foreign renewable fuel production facility is stored or transported by another company between the production facility and the vessel that transports the renewable fuel to the United States, the foreign renewable fuel producer shall obtain from each such other company a commitment that meets the requirements specified in paragraphs (f)(1) through (7) of this section, and these commitments shall be included in the foreign renewable fuel producer's application to be an approved foreign renewable fuel producer under this subpart.
(g)
(h)
(1) * * *
G = the greater of: The largest volume of renewable fuel produced by the RIN-generating foreign producer and exported to the United States, in gallons, during a single calendar year among the five preceding calendar years, or the largest volume of renewable fuel that the RIN-generating foreign producers expects to export to the Unites States during any calendar year identified in the Production Outlook Report required by § 80.1449. If the volume of renewable fuel exported to the United States increases above the largest volume identified in the Production Outlook Report during any calendar year, the RIN-generating foreign producer shall increase the bond to cover the shortfall within 90 days.
(2) Obtaining a bond in the proper amount from a third party surety agent that is payable to satisfy United States administrative or judicial judgments against the RIN-generating foreign producer, provided EPA agrees in advance as to the third party and the nature of the surety agreement.
(3) * * *
(iii) Include a commitment that the bond will remain in effect for at least five years following the end of latest annual reporting period that the RIN-generating foreign producer produces renewable fuel pursuant to the requirements of this subpart.
(4) On any occasion a RIN-generating foreign producer bond is used to satisfy any judgment, the RIN-generating foreign producer shall increase the bond to cover the amount used within 90 days of the date the bond is used.
(i)
(j) * * *
(2) No foreign renewable fuel producer or other person may cause another person to commit an action prohibited in paragraph (j)(1) of this section, or that otherwise violates the requirements of this section.
(3) No foreign renewable fuel producer or importer may generate RINs for the same volume of renewable fuel.
(4) A foreign renewable fuel producer is prohibited from generating RINs in excess of the number for which the bond requirements of this section have been satisfied.
(k) * * *
(1) Renewable fuel shall be classified as RFS-FRRF according to the designation by the RIN-generating foreign producer if this designation is supported by product transfer documents prepared by the foreign producer as required in paragraph (c) of this section.
(2) * * *
(ii) Use the RIN-generating foreign producer's RFS-FRRF certification to determine the name and EPA-assigned registration number of the RIN-generating foreign producer that produced the RFS-FRRF.
(4) * * *
(ii) The RIN-generating foreign producer, containing the information determined under paragraph (k)(2)(i) of this section, and including identification of the port at which the product was offloaded, and any RINs retired under paragraph (e)(2) of this section.
(5) Any United States importer shall meet all other requirements of this subpart for any imported renewable fuel that is not classified as RFS-FRRF under paragraph (k)(1) of this section.
(l)
(2) * * *
(i) Contracts with any facilities that receive and/or transport RFS-FRRF that prohibit the commingling of RFS-FRRF with Non-RFS-FRRF or RFS-FRRF from other foreign renewable fuel producers.
(3) The petition described in this section must be submitted to EPA along with the application for approval as a RIN-generating foreign producer under this subpart.
(m) * * *
(3) * * *
(ii) Obtain the documents used by the independent third party to determine transportation and storage of the RFS-FRRF from the RIN-generating foreign producer's facility to the load port, under paragraph (d) of this section. Obtain tank activity records for any storage tank where the RFS-FRRF is stored, and activity records for any mode of transportation used to transport the RFS-FRRF prior to being loaded onto the vessel. Use these records to determine whether the RFS-FRRF was produced at the RIN-generating foreign producer's facility that is the subject of the attest engagement, and whether the RFS-FRRF was mixed with any Non-RFS-FRRF or any RFS-FRRF produced at a different facility.
(6) * * *
(i) Be independent of the RIN-generating foreign producer;
(n)
(1) A foreign renewable fuel producer fails to meet any requirement of this section.
(3) A foreign renewable fuel producer asserts a claim of, or a right to claim, sovereign immunity in an action to enforce the requirements in this subpart.
(4) A foreign renewable fuel producer fails to pay a civil or criminal penalty
(o)
(2) Signed by the president or owner of the foreign renewable fuel producer company, or by that person's immediate designee, and shall contain the following declaration:
(i) “I hereby certify:
(A) That I have actual authority to sign on behalf of and to bind [NAME OF FOREIGN RENEWABLE FUEL PRODUCER] with regard to all statements contained herein;
(B) That I am aware that the information contained herein is being Certified, or submitted to the United States Environmental Protection Agency, under the requirements of 40 CFR part 80, subpart M, and that the information is material for determining compliance under these regulations; and
(C) That I have read and understand the information being Certified or submitted, and this information is true, complete and correct to the best of my knowledge and belief after I have taken reasonable and appropriate steps to verify the accuracy thereof.
(ii) I affirm that I have read and understand the provisions of 40 CFR part 80, subpart M, including 40 CFR 80.1465 apply to [NAME OF FOREIGN RENEWABLE FUEL PRODUCER]. Pursuant to Clean Air Act section 113(c) and 18 U.S.C. 1001, the penalty for furnishing false, incomplete or misleading information in this certification or submission is a fine of up to $10,000 U.S., and/or imprisonment for up to five years.”
(p)
(b) * * *
(1) ASTM D 1250-08 (Reapproved 2013) (“ASTM D 1250”), Standard Guide for Use of the Petroleum Measurement Tables, Approved October 1, 2013; IBR approved for § 80.1426(f)(8)(ii)(B).
(3) ASTM D 4444-13 (“ASTM D 4444”), Standard Test Method for Laboratory Standardization and Calibration of Hand-Held Moisture Meters, Approved April 1, 2013; IBR approved for § 80.1426(f)(7)(v)(B).
(4) ASTM D 6751-15 (“ASTM D 6751”), Standard Specification for Biodiesel Fuel Blend Stock (B100) for Middle Distillate Fuels, Approved January 1, 2015, IBR approved for § 80.1401.
(5) ASTM D 6866-08 (“ASTM D 6866”), Standard Test Methods for Determining the Biobased Content of Solid, Liquid, and Gaseous Samples Using Radiocarbon Analysis, Approved 2008; IBR approved for §§ 80.1426(f)(9)(ii), 80.1430(e)(2), and 80.1433(c)(2).
(7) ASTM E 870-82 (Reapproved 2006) (“ASTM E 870”), Standard Test Methods for Analysis of Wood Fuels, Approved November 1, 2006; IBR approved for § 80.1426(f)(7)(v)(A).
(8) ASTM D 975-15, Standard Specification for Diesel Fuel Oils, Approved March 1, 2015; IBR approved for §§ 80.1401, 80.1426(f), 80.1450(b), 80.1451(b), and 80.1454(l).
The revisions and additions read as follows:
(c) * * *
(1) * * *
(ii) If applicable, plans under § 80.1426(f)(5)(ii) are accepted and up to date.
(vi) Feedstock(s) and biointermediate(s) are consistent with production process and D code being used as permitted under Table 1 to § 80.1426 or a petition approved through § 80.1416, and is consistent with information recorded in EMTS.
(vii) Feedstock(s) and biointermediate(s) are not renewable fuel for which RINs were previously generated.
(4) * * *
(iv) Verify that RINs that needed to be separated under § 80.1429(b)(11) and RINs that must be retired under § 80.1433 were appropriately separated and retired, as applicable.
(6)
(i)(A) Verify that the end-user(s) of any VRD-N have converted vehicles and engines to use such fuel under an EPA-approved Clean Alternative Fuel Conversion under 40 CFR part 85, subpart F, if applicable.
(B) Verify documentation demonstrating that end-user(s) can use VRD-N as heating oil or jet fuel, if applicable.
(ii) Verify that any VRD-N has been used by the end-user(s) of the VRD-N as transportation fuel, heating oil, or jet fuel.
(iii) Ensure that the VRD-N producer did not generate RINs for any volume of VRD-N prior to verification by an independent third-party auditor.
(iv) Independent third-party auditors shall not use representative sampling as described in paragraph (c)(5) of this section for the verification of VRD-N.
(e) * * *
(3) A QAP is approved on the date that the EPA notifies the third-party independent auditor of such approval or if all of the conditions specified in § 80.1450(g)(10) are met.
(4) The EPA may revoke its approval of a QAP, in whole or in part (
(f) * * *
(1) A new QAP shall be submitted to the EPA according to paragraph (e) of this section and the third-party auditor shall update their registration according to § 80.1450(g)(9) whenever any of the following changes occur at a production facility audited by a third-party independent auditor and the auditor does not possess an appropriate pathway-specific QAP that encompasses the changes:
(i) Change in feedstock, including biointermediates.
The revisions and additions read as follows:
(b) To be considered an independent third-party auditor under this section, all of the following conditions must be met:
(1) The independent third-party auditor and its contractors and subcontractors shall not be owned or operated by the renewable fuel producer, foreign ethanol producer, or biointermediate producer, or any subsidiary or employee of the renewable fuel producer, foreign ethanol producer, or biointermediate producer.
(4) The independent third-party auditor and its contractors and subcontractors shall be free from any interest or the appearance of any interest in the renewable fuel producer, foreign ethanol producer, or biointermediate producer's business.
(5) The renewable fuel producer, foreign ethanol producer, or biointermediate producer shall be free from any interest or the appearance of any interest in the third-party auditor's business and the businesses of the third-party auditor's contractors and subcontractors.
(6) The independent third-party auditor and its contractors and subcontractors shall not have performed an attest engagement under § 80.1464 for the renewable fuel producer, foreign ethanol producer, or foreign renewable fuel producer in the same calendar year it performed a QAP audit pursuant to § 80.1472 for the same entities.
(8) The independent third-party auditor and its contractors and subcontractors shall act impartially when performing all activities under this section.
(9) The independent third-party auditor and its contractors and subcontractors shall be free from any interest in the renewable fuel producer, foreign ethanol producer, or biointermediate producer's business and receive no financial benefit from the outcome of the registration, apart from payment for the auditing services.
(10) The independent third-party auditor and its contractors and subcontractors shall not have conducted past research, development, design, construction, or consulting for the renewable fuel producer, foreign ethanol producer, or biointermediate producer within the last three years. For purposes of this requirement, consulting does not include performing or participating in verification activities pursuant to this section.
(11) The independent third-party auditor and its contractors and subcontractors shall not provide other business or consulting services to the renewable fuel producer, foreign ethanol producer, or biointermediate producer, including advice or assistance to implement the findings or recommendations in an audit report, for a period of at least three years following submission of the its final QAP audit.
(12) The independent third-party auditor and its contractors and subcontractors shall ensure that all personnel involved in the third-party audit (including the verification activities) under this section do not accept future employment with the owner or operator of the renewable fuel producer, foreign ethanol producer, or biointermediate producer for a period of at least three years. For purposes of this requirement, employment does not include performing or participating in the third-party audit (including the verification activities) pursuant to § 80.1472.
(13) The independent third-party auditor and its contractors and subcontractors shall have written policies and procedures to ensure that the independent third-party auditor and all personnel under the independent third-party auditor's direction or supervision comply with the competency, independence, and impartiality requirements of this section.
(14) The independent third-party auditor and its contractors and subcontractors shall not have performed an engineering review under § 80.1450(b)(2) for the renewable fuel producer, foreign ethanol producer, or biointermediate producer.
(e) The independent third-party auditor shall identify RINs generated from a renewable fuel producer as having been verified under a QAP.
(4) The independent third-party auditor shall not identify RINs generated from a renewable fuel producer as having been verified under a QAP if a revised QAP must be submitted to and approved by EPA under § 80.1469(f).
(5) The independent third-party auditor shall not identify RINs generated for renewable fuel produced using a biointermediate as having been verified under a QAP unless the biointermediate used to produce the renewable fuel was verified under an approved QAP pursuant to § 80.1476.
(b) * * *
(3) * * *
(i) As applicable, the independent third-party auditor shall conduct an on-site visit at the renewable fuel production facility, foreign ethanol production facility, or biointermediate production facility:
(ii) * * *
(B) 380 days after the previous on-site visit if a previously approved (by EPA) remote monitoring system is in place at the renewable fuel production facility, foreign ethanol production facility, and biointermediate production facility, as applicable. The 380-day period shall start the day after the previous on-site visit ends.
(iii) An on-site visit shall include verification of all QAP elements that require inspection or evaluation of the physical attributes of the renewable fuel production facility, foreign ethanol production facility, or biointermediate production facility, as applicable.
(v) Any on-site visit specified in paragraph (b)(3)(i) of this section shall occur while the facility is producing renewable fuel, undenatured ethanol, or a biointermediate. If the facility is not operational at the time of the third-party on-site visit, then all of the following requirements apply:
(A) The responsible corporate officer for the renewable fuel producer, foreign ethanol producer, or biointermediate producer must provide the third-party auditor with a signed affidavit explaining why the facility is not operational.
(B) If the facility is not operational because of a maintenance issue, the renewable fuel producer, foreign ethanol producer, or biointermediate producer must provide the third-party auditor with supporting written documentation of the maintenance issue.
(C) The independent third-party auditor shall include the reason why the facility was not operational in their
(D) The independent third-party auditor shall not verify RINs for the renewable fuel producer under § 80.1471(e) until after an on-site visit occurs while the facility is operational.
(g)
(i) The date(s) the surface leak occurred.
(ii) The facility identification number associated with the 40 CFR part 98, subpart RR, annual GHG report of the geologic sequestration facility.
(iii) The facility identification number associated with the 40 CFR part 98, subpart PP, annual GHG report of the renewable fuel production facility.
(iv) A detailed description of how the leak occurred.
(v) The amount of CO
(vi) A description of corrective actions that when taken, would remediate the surface leak.
(vii) A list of all PIRs affected by the surface leak.
(viii) The original calculated greenhouse gas emissions for each affected batch of renewable fuel.
(ix) The updated calculated greenhouse gas emissions for each affected batch of renewable fuel that accounts for the surface leak.
(x) A plan detailing how the RIN generator intends to remediate all PIRs generated as a result of the surface leak.
(xi) A demonstration from the renewable fuel producer that all necessary steps are being taken to ensure there will be no CO
(xii) Any other information requested by EPA.
(2) If EPA determines that the surface leak has caused the PIR(s) to be invalid, the PIR generator must retire the PIR or a valid RIN following the requirements of paragraph (d) of this section within 30 days of notification by EPA.
Biointermediate producers shall comply with the following requirements:
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(2) Beginning January 1, 2018, or a later date designated by EPA, a biointermediate producer may designate and transfer a biointermediate to more than one renewable fuel production facility.
(3) The EPA in its sole discretion may allow a biointermediate producer to designate and transfer a biointermediate to more than one renewable fuel production facility prior to January 1, 2018, or a later date designated by EPA.
(h)
(i)
(a) Independent third-party auditors that verify biointermediate production must meet the requirements of § 80.1471(a) through (c) and (g) through (h).
(b) QAPs approved by EPA to verify biointermediate production must meet the requirements in § 80.1469(c) through (f), as applicable.
(c) Quality assurance audits, when performed, shall be conducted in accordance with the requirements in § 80.1472(a) and (b)(3).
(d)(1) If a third-party auditor identifies a potentially improperly produced biointermediate, the third-party auditor shall notify EPA, the biointermediate producer, and any renewable fuel producers that may have been transferred the biointermediate in writing within five business days of the identification, including an initial explanation of why the biointermediate may have been improperly produced.
(2) If RINs were generated from the potentially improperly produced biointermediate, the RIN generator shall follow the identification and treatment of PIR procedures as specified in § 80.1474.
(e) For the generation of Q-RINs for renewable fuels that were produced from a biointermediate, the biointermediate must be verified under an approved QAP as described in paragraph (b) of this section and the RIN generating facility must be verified under an approved QAP as described in § 80.1469.
(a)
(b)
(c)
(1) Any EPA inspector or auditor must be given full, complete, and immediate access to conduct inspections and audits of the foreign biointermediate producer facility.
(i) Inspections and audits may be either announced in advance by EPA, or unannounced.
(ii) Access will be provided to any location where:
(A) Biointermediate is produced.
(B) Documents related to foreign biointermediate producer operations are kept.
(C) Biointermediate is stored or transported between the foreign biointermediate producer and the renewable fuel producer, including storage tanks, vessels, and pipelines.
(iii) EPA inspectors and auditors may be EPA employees or contractors to EPA.
(iv) Any documents requested that are related to matters covered by inspections and audits must be provided to an EPA inspector or auditor on request.
(v) Inspections and audits may include review and copying of any documents related to the following:
(A) The volume of biointermediate produced and/or delivered to renewable fuel production facilities.
(B) Transfers of title or custody to the biointermediate.
(C) Work performed and reports prepared by independent third parties and by independent auditors under the requirements of this section, including work papers.
(vi) Inspections and audits by EPA may include interviewing employees.
(vii) Any employee of the foreign biointermediate producer must be made available for interview by the EPA inspector or auditor, on request, within a reasonable time period.
(viii) English language translations of any documents must be provided to an EPA inspector or auditor, on request, within 10 working days.
(ix) English language interpreters must be provided to accompany EPA inspectors and auditors, on request.
(2) An agent for service of process located in the District of Columbia shall be named, and service on this agent constitutes service on the foreign biointermediate producer or any employee of the foreign biointermediate producer for any action by EPA or otherwise by the United States related to the requirements of this subpart.
(3) The forum for any civil or criminal enforcement action related to the provisions of this section for violations of the Clean Air Act or regulations promulgated thereunder shall be governed by the Clean Air Act, including the EPA administrative forum where allowed under the Clean Air Act.
(4) United States substantive and procedural laws shall apply to any civil or criminal enforcement action against the foreign biointermediate producer or any employee of the foreign biointermediate producer related to the provisions of this section.
(5) Applying to be an approved foreign biointermediate producer under this section, or producing or exporting biointermediate under such approval, and all other actions to comply with the requirements of this subpart relating to such approval constitute actions or activities covered by and within the meaning of the provisions of 28 U.S.C. 1605(a)(2), but solely with respect to actions instituted against the foreign biointermediate producer, its agents and employees in any court or other tribunal in the United States for conduct that violates the requirements applicable to the foreign biointermediate producer under this subpart, including conduct that violates the False Statements Accountability Act of 1996 (18 U.S.C. 1001) and section 113(c)(2) of the Clean Air Act (42 U.S.C. 7413).
(6) The foreign biointermediate producer, or its agents or employees, will not seek to detain or to impose civil or criminal remedies against EPA inspectors or auditors for actions performed within the scope of EPA employment or contract related to the provisions of this section.
(7) The commitment required by this paragraph shall be signed by the owner or president of the foreign biointermediate producer company.
(8) In any case where the biointermediate produced at a foreign biointermediate production facility is stored or transported by another company between the production facility and the vessel that transports the renewable fuel to the United States, the foreign biointermediate producer shall obtain from each such other company a commitment that meets the requirements specified in paragraphs (c)(1) through (7) of this section, and these commitments shall be included in the foreign biointermediate producer's application to be an approved foreign biointermediate producer under this subpart.
(d)
(e)
(f)
(g)
(1) A foreign biointermediate producer fails to meet any requirement of this section.
(2) A foreign government fails to allow EPA inspections or audits as provided in paragraph (c)(1) of this section.
(3) A foreign biointermediate producer asserts a claim of, or a right to claim, sovereign immunity in an action to enforce the requirements in this subpart.
(h)
(1) Submitted in accordance with procedures specified by the Administrator, including use of any forms that may be specified by the Administrator.
(2) Signed by the president or owner of the foreign biointermediate producer company, or by that person's immediate designee, and must contain the following declaration:
(i) “I hereby certify:
(A) That I have actual authority to sign on behalf of and to bind [NAME OF FOREIGN BIOINTERMEDIATE PRODUCER] with regard to all statements contained herein;
(B) That I am aware that the information contained herein is being Certified, or submitted to the United States Environmental Protection Agency, under the requirements of 40 CFR part 80, subpart M, and that the information is material for determining compliance under these regulations; and
(C) That I have read and understand the information being Certified or submitted, and this information is true, complete and correct to the best of my knowledge and belief after I have taken reasonable and appropriate steps to verify the accuracy thereof.
(ii) I affirm that I have read and understand the provisions of 40 CFR part 80, subpart M, including 40 CFR 80.1465 apply to [NAME OF FOREIGN BIOINTERMEDIATE PRODUCER]. Pursuant to Clean Air Act section 113(c) and 18 U.S.C. 1001, the penalty for furnishing false, incomplete or misleading information in this certification or submission is a fine of up to $10,000 U.S., and/or imprisonment for up to five years.”
(i)
(1) For each biointermediate batch, any biointermediate importer shall have an independent third party do all the following:
(i) Determine the volume of biointermediate in the vessel.
(ii) Determine the name and EPA-assigned registration number of the foreign biointermediate producer that produced the biointermediate.
(iii) Determine the name and country of registration of the vessel used to transport the biointermediate to the United States.
(iv) Determine the date and time the vessel arrives at the United States port of entry.
(2) Any biointermediate importer shall submit reports within 30 days following the date any vessel transporting biointermediate arrives at the United States port of entry to all the following:
(i) The Administrator, containing the information determined under paragraph (h)(1) of this section.
(ii) The foreign biointermediate producer, containing the information determined under paragraph (h)(1) of this section, and including identification of the port at which the product was offloaded.
(3) The biointermediate importer and the third-party auditor must keep records of the audits and reports required under paragraphs (h)(1) and (2) of this section for five years from the date of creation.
Biogas producers shall comply with the following requirements:
(a)
(2) No later than the effective date of the final rule, or 60 days prior to the generation of RINs from biogas produced from a biogas producer, whichever is later, biogas producers and the RIN generating party must associate in the EPA's Central Data Exchange using forms and procedures as prescribed by the Administrator.
(3) Biogas producers must update their registrations as described in § 80.1450(d).
(b)
(c)
(2) Biogas producers that register as biointermediate producers shall not generate RINs.
(3) Renewable fuel producers shall only generate RINs for renewable fuel produced from biogas sourced from a biogas producer that satisfies the requirements of this section.
(d)
(2) Biogas producers that register as biointermediate producers shall submit reports to the EPA as described in § 80.1451(i).
(e)
(2) Biogas producers that register as biointermediate producers shall comply with annual attest engagement requirements as described in § 80.1464(h).
(f)
(g)
(h)
(i)
(j)
(a)
(2) The VRD-N producer must satisfy all requirements specified in this subpart for renewable fuel producers (including but not limited to registration, recordkeeping, and reporting requirements).
(3) RINs may only be generated for VRD-N after an independent third-party auditor has verified the use of the fuel as transportation fuel, heating oil, or jet fuel under an EPA-approved QAP as described in § 80.1469.
(b)
(2) RINs shall not be assigned to finished fuel, but shall be treated as separated RINs immediately upon generation.
(3) VRD blenders must satisfy all requirements specified in this subpart for renewable fuel producers that are using a biointermediate (including, but not limited to, registration, recordkeeping, and reporting requirements). In applying such requirements, the facility at which VRD-B is blended with petroleum diesel shall be considered the renewable fuel production facility and the VRD-B producer shall be considered the biointermediate producer.
(4) VRD-B producers must satisfy the requirements of paragraph (c) of this section.
(c)
(1)
(2)
(3)
(4)
(5)
(6)
(7)
(8)
(9)
(10)
(11)
(a) Unless otherwise defined in paragraph (b) of this section, the definitions in § 80.2 apply to this subpart, including, but not limited to, the definitions for the following terms:
(b) The following definitions apply for the purposes of this subpart:
(i) Densely populated areas;
(ii) Transportation corridors; and
(iii) Remaining areas.
(a) The following fuels are subject to the standards and requirements of this subpart:
(1) Reformulated and conventional gasoline, RBOB, and CBOB (collectively called “gasoline” unless otherwise specified).
(2) Any blendstock blended with PCG.
(3) Oxygenates blended with gasoline, RBOB, or CBOB.
(4) Ethanol flex fuel.
(5) Certified and uncertified natural gasoline ethanol flex fuel blendstock.
(b) The following fuels are not subject to the standards and requirements of this subpart:
(1) Gasoline and ethanol flex fuel that is used to fuel aircraft, racing vehicles, or racing boats that are used only in sanctioned racing events, provided that the following requirements are met:
(i) Product transfer documents associated with such gasoline and ethanol flex fuel, and labels from any pump stand from which such gasoline and ethanol flex fuel is dispensed, identify the gasoline and ethanol flex fuel either as gasoline or ethanol flex fuel that is restricted for use in aircraft, or as gasoline or ethanol flex fuel that is restricted for use in racing motor vehicles or racing boats that are used only in sanctioned racing events.
(ii) The gasoline and ethanol flex fuel is completely segregated from all other gasoline and ethanol flex fuel throughout production, distribution, and sale to the ultimate consumer.
(iii) The gasoline and ethanol flex fuel is not made available for use as motor vehicle gasoline and ethanol flex fuel, or dispensed for use in motor vehicles, except for motor vehicles used only in sanctioned racing events.
(2) California gasoline as defined in § 80.1600 and subject to the provisions of § 80.1654.
(3) California ethanol flex fuel as defined in § 80.1500 and subject to the provisions of § 80.1558.
(4) Gasoline and ethanol flex fuel that is exported for sale and use outside the United States.
(5) Exempt fuels under §§ 80.1555 (national security exemptions), 80.1556 (ethanol flex fuel used for research, development, or testing purposes), and 80.1557 (ethanol flex fuel used in American Samoa, Guam, and the Commonwealth of the Northern Mariana Islands).
The revisions read as follows:
(b) * * *
(3) * * *
(i) The word “ATTENTION” shall be capitalized in 20-point, black, Helvetica Neue LT 77 Bold Condensed font, and shall be placed in the top 1.25 inches of the label as further described in paragraph (b)(4)(iii) of this section.
(5) * * *
(i) A request for approval of an alternative label shall be sent to the attention of “E15 Alternative Label Request” to the address in § 80.10(a).
The provisions of § 80.9 apply for purposes of determining the ethanol content, sulfur content, benzene content, or Reid vapor pressure (RVP) of any fuel, blendstock, or oxygenate subject to this subpart.
(a)
(2) Any natural gasoline ethanol flex fuel blendstock refiner or importer must register by October 1, 2017, or at least 60 days in advance of the first date that such person will produce or import certified natural gasoline ethanol flex fuel blendstock, whichever is later.
(b)
(2) Any blender pump-refiner must comply with the requirements of this subpart by February 1, 2018, or the first date that such person blends ethanol flex fuel, whichever is later. Such parties must also comply with the RVP requirements in § 80.1520(c) from June 1 through September 15 each year beginning June 1, 2018, through September 15, 2018.
(3) Any certified natural gasoline ethanol flex fuel blendstock refiner or importer must comply with the requirements of this subpart by December 1, 2017, or the first date that such person produces or imports natural gasoline ethanol flex fuel blendstock, whichever is later.
(4) Any party in the ethanol flex fuel production and distribution system except for retail and wholesale purchaser consumer facilities must comply with the RVP requirements in § 80.1520(c) from May 1 through September 15 each year beginning May 1, 2018, through September 15, 2018.
(5) Any ethanol flex fuel retail or wholesale purchaser consumer facility must comply with the RVP requirements in § 80.1520(c) from June 1 through September 15 each year beginning June 1, 2018, through September 15, 2018.
(c)
(ii) For annual average standards, the averaging period is a calendar year (January 1 through December 31) or any part thereof during which ethanol flex fuel is produced, imported, sold, offered for sale, dispensed, supplied, offered for supply, stored, or transported for use.
(2)
(3)
(4)
(5)
(a)
(b)
(B) [Reserved]
(ii)
(B) For all other ethanol flex fuel, the sulfur per-gallon cap standard is a maximum of 95 ppm.
(2)
(B) [Reserved]
(ii) [Reserved]
(3)
(c)
(a)
(b)
(1) Ethanol that meets the requirements of paragraph (b)(1)(i) or (b)(1)(ii) of this section, as applicable.
(i) Denatured fuel ethanol that meets the requirements of § 80.1610.
(ii) Undenatured ethanol at an ethanol production facility that has a sulfur content not greater than 10 ppm and is composed solely of carbon, hydrogen, nitrogen, oxygen, and sulfur unless a waiver has been granted under 42 U.S.C. 7545(f)(4).
(2) For ethanol flex fuel sold, offered for sale, dispensed, supplied, or offered for supply in areas other than the reformulated gasoline areas described in § 80.70:
(i) Conventional gasoline or CBOB that meets the applicable requirements of this part, including subparts L and O.
(ii) Reformulated gasoline or RBOB that meets the applicable requirements of this part, including subparts D, L, and O.
(3) For ethanol flex fuel sold, offered for sale, dispensed, supplied, or offered for supply in the reformulated gasoline areas described in § 80.70:
(i) Reformulated gasoline or RBOB that meets the applicable requirements of this part, including subparts D, L, and O.
(ii) [Reserved]
(4) Certified natural gasoline ethanol flex fuel blendstock that meets the requirements of § 80.1524.
(5) Uncertified natural gasoline ethanol flex fuel blendstock that meets the following requirements:
(i)
(B) Compliance with the RVP standard in paragraph (b)(5)(i)(A) of this section shall be determined by sampling and testing each batch of uncertified natural gasoline ethanol flex fuel blendstock pursuant to § 80.1553(g).
(ii)
(B) Compliance with the T90 distillation point and final distillation point standards in paragraph (b)(5)(ii)(A) of this section shall be determined by sampling and testing each batch pursuant to § 80.1553(h).
(iii)
(B) To demonstrate compliance with the elemental composition requirements in paragraph (b)(5)(iii)(A) of this section, the uncertified natural gasoline ethanol flex fuel blendstock must have been produced from a processing unit (
(6) The combined concentration of certified and uncertified natural gasoline ethanol flex fuel blendstock blended to produce ethanol flex fuel must not exceed 30 volume percent. This 30 volume percent cap on the amount of natural gasoline that may be blended to produce ethanol flex fuel is in addition to the amount of natural gasoline that may be added to denature the denatured fuel ethanol used as an ethanol flex fuel blendstock pursuant to the requirements of § 80.1610(a)(4).
(7) Ethanol flex fuel additives that meet the requirements of § 80.1525.
(c)
(2)
(ii) The annual average sulfur level calculation in paragraph (c)(2)(i) of this section shall be conducted to two decimal places using the rounding procedure specified in § 80.1503.
(3)
(d)
(2)
(ii) The annual benzene level calculation in paragraph (d)(2)(i) of this section shall be conducted to two decimal places using the rounding procedure specified in § 80.1503.
(e)
(f)
(g)
(a)
(b)
(1) Ethanol that meets the requirements of paragraph (b)(1)(i) or (ii) of this section, as applicable.
(i) Denatured fuel ethanol that meets the requirements of § 80.1610.
(ii) Undenatured ethanol at an ethanol production facility that has a sulfur content not greater than 10 ppm and is composed solely of carbon, hydrogen, nitrogen, oxygen, and sulfur unless a waiver has been granted under 42 U.S.C. 7545(f)(4).
(2) For ethanol flex fuel sold, offered for sale, dispensed, supplied, or offered for supply in areas other than the reformulated gasoline areas described in § 80.70:
(i) Conventional gasoline or CBOB that meets the applicable requirements of this part, including subparts L and O.
(ii) Reformulated gasoline or RBOB that meets the applicable requirements of this part, including subparts D, L, and O.
(3) For ethanol flex fuel sold, offered for sale, dispensed, supplied, or offered for supply in the reformulated gasoline areas described in § 80.70:
(i) Reformulated gasoline or RBOB that meets the applicable requirements of this part, including subparts D, L, and O.
(ii) [Reserved]
(4) Certified natural gasoline ethanol flex fuel blendstock that meets the requirements of § 80.1524. The concentration of certified natural gasoline ethanol flex fuel blendstock blended to produce ethanol flex fuel shall be limited to 30 volume percent. This 30 volume percent cap on the amount of natural gasoline that may be blended to produce ethanol flex fuel is in addition to the amount natural gasoline that may be added to denature the denatured fuel ethanol used as an ethanol flex fuel blendstock pursuant to the requirements of § 80.1610(a)(4).
(5) Ethanol flex fuel additives that meet the requirements of § 80.1525.
(c)
(2)
(d)
(a)
(b)
(1) Ethanol flex fuel produced by an ethanol flex fuel full-refiner or imported by an ethanol flex fuel importer that meets the requirements of §§ 80.1520 and 80.1521, or produced by an ethanol flex fuel bulk blender-refiner that meets the requirements of §§ 80.1520 and 80.1522.
(2) For ethanol flex fuel sold, offered for sale, dispensed, supplied, or offered for supply in areas other than the reformulated gasoline areas described in § 80.70:
(i) Conventional gasoline that meets the applicable requirements of this part, including subparts L and O.
(ii) Reformulated gasoline that meets the applicable requirements of this part, including subparts D, L, and O.
(3) For ethanol flex fuel sold, offered for sale, dispensed, supplied, or offered for supply in the reformulated gasoline areas described in § 80.70:
(i) Reformulated gasoline that meets the applicable requirements of this part, including subparts D, L, and O.
(ii) [Reserved]
(4) Ethanol flex fuel additives that meet the requirements of § 80.1525.
(c)
(2)
(a)
(b)
(2) The sulfur content of certified natural gasoline ethanol flex fuel blendstock shall be determined by sampling and testing each batch pursuant to § 80.1553(e).
(c)
(2) The benzene content of certified natural gasoline ethanol flex fuel blendstock shall be determined by sampling and testing each batch pursuant to § 80.1553(f).
(d)
(2) Compliance with the RVP standard in paragraph (d)(1) of this section shall be determined by sampling and testing each batch of certified natural gasoline ethanol flex fuel blendstock pursuant to § 80.1553(g).
(e)
(2) Compliance with the T90 distillation point and final distillation point standards in paragraph (e)(1) of this section shall be determined by sampling and testing each batch pursuant to § 80.1553(h).
(f)
(2) To demonstrate compliance with the elemental composition requirements in paragraph (f)(1) of this section, the uncertified natural gasoline ethanol flex fuel blendstock must have been produced from a processing unit (
(g)
(h) Natural gasoline ethanol flex fuel blendstock cannot be sold as gasoline or used as a gasoline blendstock unless the party that uses natural gasoline to manufacture gasoline complies with all applicable gasoline refiner requirements in 40 CFR part 80, including subparts L and O. Natural gasoline ethanol flex fuel blendstock may not be commingled with gasoline unless it is being blended with gasoline by an ethanol flex fuel full-refiner or ethanol flex fuel bulk blender-refiner in the process of producing ethanol flex fuel.
(i) No additives may be added to certified natural gasoline ethanol flex fuel blendstock after the point of production or importation.
(a) Ethanol flex fuel additive manufacturers must meet the following requirements:
(1) Except as otherwise provided, this section applies to any ethanol flex fuel additive manufactured for use in ethanol flex fuel and is sold for use at a concentration of less than 1.0% by volume.
(2) The ethanol flex fuel additive must contribute no more than 3 ppm on a per-gallon basis to the sulfur content of ethanol flex fuel when used at the maximum recommended treatment rate.
(3) The ethanol flex fuel additive manufacturer must maintain records of its additive production quality control activities that demonstrates that the sulfur content of its additive production batches complies with the sulfur requirement in paragraph (a)(2) of this section and make these records available to EPA upon request.
(4) The ethanol flex fuel additive shall be composed solely of carbon, hydrogen, oxygen, nitrogen, and/or sulfur, unless a waiver has be granted under 42 U.S.C. 7545(f)(4).
(5) The maximum treatment rate on the product transfer document for the additive must state all the following:
(i) The maximum concentration.
(ii) The maximum allowed treatment rate that corresponds to the maximum concentration. The maximum allowed concentration must comply with the requirements in paragraph (a)(2) of this section.
(b) The following provisions in paragraphs (b)(1) and (2) of this section apply to parties who are downstream of the ethanol flex fuel refiner or ethanol flex fuel importer and who blend additives into ethanol flex fuel.
(1) On any occasion where an ethanol flex fuel additive blender blends an ethanol flex fuel additive (subject to the requirements of this section) at a concentration of less than 1.0% by volume, it is subject to the prohibitions in § 80.1564 and the ethanol flex fuel sulfur standards of § 80.1520(b)(1).
(2) On any occasion where an ethanol flex fuel additive blender blends an ethanol flex fuel additive at a concentration of 1.0% by volume or greater, it is a fuel manufacturer as defined in § 79.2(d) of this chapter, and is subject to all the provisions that apply to ethanol flex fuel refiners and importers under this subpart.
(a)
(i) Ethanol flex fuel produced by an ethanol flex fuel full-refiner or imported by an ethanol flex fuel importer that meets the requirements of §§ 80.1520 and 80.1521, or produced by an ethanol flex fuel bulk blender-refiner that meets the requirements of §§ 80.1520 and 80.1522.
(ii) For E15 sold, offered for sale, dispensed, supplied, or offered for supply in areas other than the reformulated gasoline areas described in § 80.70:
(A) Conventional gasoline that meets the applicable requirements of this part, including subparts L and O.
(B) Reformulated gasoline that meets the applicable requirements of this part, including subparts D, L, and O.
(iii) For E15 sold, offered for sale, dispensed, supplied, or offered for supply in the reformulated gasoline areas described in § 80.70:
(A) Reformulated gasoline that meets the applicable requirements of this part, including subpart D, L, and O.
(B) [Reserved]
(iv) Gasoline additives that meet the requirements of § 80.1613.
(2) Beginning February 1, 2018, and thereafter, a blender pump-refiner that produces E15 may demonstrate compliance with the gasoline registration requirements in 40 CFR part 79 and the gasoline refiner requirements in this part, including those that pertain to the volatility standards for conventional gasoline in subpart B of this part and those that pertain to the hydrocarbon standard for reformulated gasoline in subpart D of this part, by complying with the requirements in paragraph (b) of this section and using only the following components to produce E15:
(i) Ethanol flex fuel produced by an ethanol flex fuel full-refiner or imported by an ethanol flex fuel importer that meets the requirements of §§ 80.1520 and 80.1521, or produced by an ethanol flex fuel bulk blender-refiner that meets the requirements of §§ 80.1520 and 80.1522.
(ii) For E15 sold, offered for sale, dispensed, supplied, or offered for supply in areas where the 1 psi RVP waiver for E10 in § 80.27(d) does not apply other than the reformulated gasoline areas described in § 80.70:
(A) E10 conventional gasoline that meets the applicable requirements of this part, including subparts L and O.
(B) E10 reformulated gasoline that meets the applicable requirements of this part, including subparts D, L, and O.
(iii) For E15 sold, offered for sale, dispensed, supplied, or offered for supply in the reformulated gasoline areas described in § 80.70:
(A) E10 reformulated gasoline that meets the applicable requirements of this part, including subpart D, L, and O.
(B) [Reserved]
(iv) Gasoline additives that meet the requirements of § 80.1613.
(b)
(a)
(1)
(2)
(3)
(4)
(5)
(6)
(7)
(8)
(9)
(10)
(11)
(12)
(13)
(14)
(15)
(16)
(17)
(18)
(19)
(20)
(21)
(22)
(23)
(24)
(25)
(26)
(27)
(28)
(29)
(30)
(31)
(32)
(33)
(34)
(35)
(36)
(37)
(38)
(39)
(40)
(41)
(42)
(43)
(44)
(45)
(46)
(47)
(48)
(b)
(c)
The following registration requirements apply under this subpart:
(a)
(1) Any ethanol flex fuel full-refiner or importer.
(2) Any ethanol flex fuel bulk blender-refiner.
(3) Any certified natural gasoline ethanol flex fuel blendstock refiner or importer.
(b)
(i) The name, business address, contact name, email address, and telephone number of the refiner or importer.
(ii) For each separate refinery or import facility, the facility name, physical location, contact name, email address, telephone number, and type of facility.
(iii) For each separate refinery or importer's operations in a single Petroleum Administration for Defense District (PADD)—
(A) Whether records are kept on-site or off-site of the refinery or import facility's registered address.
(B) If records are kept off-site, the primary off-site storage facility name, physical location, contact name, email address, and telephone number.
(iv) The type(s) of ethanol flex fuel or natural gasoline ethanol flex fuel blendstock that is produced, imported, or blended.
(v) Registrations for certified natural gasoline ethanol flex fuel blendstock refiners and importers must contain sufficient information to demonstrate that the refiner produces natural gasoline ethanol flex fuel blendstock solely from natural gas processing plants or a crude oil refineries.
(2) EPA will supply a company registration number to each refiner or importer and a facility registration number for each refinery or import facility that is identified. These registration numbers shall be used in all reports to the Administrator.
(3) Any refiner or importer shall submit updated registration information to the Administrator within thirty days of any occasion when the registration information previously supplied becomes incomplete or inaccurate.
Beginning with the compliance date specified in § 80.1504(b) and continuing for each averaging period thereafter, any ethanol flex fuel full-refiner, ethanol flex fuel importer, ethanol flex fuel bulk blender-refiner, certified natural gasoline ethanol flex fuel blendstock refiner, or certified natural gasoline ethanol flex fuel blendstock importer, shall submit annual reports to EPA that contain the information required in this section, and any other information as EPA may require. Reporting shall be on forms and use procedures prescribed by the Administrator. Blender pump-refiners that comply with the requirements of § 80.1523 are exempt from the annual reporting requirements of this section.
(a)
(1) The EPA-issued company registration number.
(2) The EPA-issued facility registration number.
(3) The total volume of ethanol flex fuel produced or imported, in gallons, reported to the nearest whole number.
(4) For each batch of ethanol flex fuel produced or imported during the calendar year, all of the following:
(i) The batch number assigned under § 80.1521(g).
(ii) The date the batch was produced.
(iii) The volume of the batch, in gallons, reported to the nearest whole number.
(iv) The volume percent ethanol content of the batch, reported to one decimal place.
(v) The sulfur content of the batch, reported to the nearest ppm, and the benzene content of the batch, reported to two decimal places, along with identification of the test methods used to determine the sulfur content and benzene content of the batch, as determined under § 80.1553(e) and (f), respectively.
(vi) For batches sold, offered for sale, dispensed, supplied, or offered for supply from May 1 through September 15, the RVP of the batch, reported to two decimal places, along with identification of the test method used to determine the RVP of the batch, as determined under § 80.1553(g).
(vii) The type and volume of each hydrocarbon and ethanol blendstock that was used to produce the ethanol flex fuel, as applicable (
(5) The annual average sulfur level and annual average benzene level of the ethanol flex fuel produced or imported, reported to two decimal places.
(6) Certification that all batches of ethanol flex fuel produced or imported
(b)
(1) The EPA importer, or refiner and refinery facility registration numbers.
(2) The total volume of ethanol flex fuel produced, in gallons, reported to the nearest whole number.
(3) For each batch of ethanol flex fuel blended during the calendar year, all of the following:
(i) The batch number assigned under § 80.1522(d).
(ii) The date the batch was produced.
(iii) The volume of the batch, in gallons, reported to the nearest whole number.
(iv) The ethanol content of the batch, reported to one decimal place.
(v) For batches sold, offered for sale, dispensed, supplied, or offered for supply from May 1 through September 15, the RVP of the batch, reported to two decimal places, and the method used to demonstrate compliance with the applicable RVP standard, as determined by either:
(A) The use of an EPA-approved RVP compliance tool under § 80.1553(j).
(B) A test method pursuant to the requirements of § 80.1553(g).
(vi) The type and volume of each hydrocarbon and ethanol blendstock that was used to produce the ethanol flex fuel, as applicable (
(4) Certification that all batches of ethanol flex fuel blended were compliant with the requirements of §§ 80.1520 and 80.1522.
(c)
(1) The EPA-issued company registration number.
(2) The EPA-issued facility registration number.
(3) The total volume of certified natural gasoline ethanol flex fuel blendstock produced or imported during the calendar year, in gallons, reported to the nearest whole number.
(4) For each batch of certified natural gasoline flex fuel blendstock produced or imported during the calendar year, all of the following:
(i) The batch number assigned under § 80.1524(g).
(ii) The date the batch was produced.
(iii) The volume of the batch, in gallons, reported to the nearest whole number.
(iv) The sulfur content of the batch, reported to the nearest ppm, and the benzene content of the batch, reported to two decimal places, along with identification of the test methods used to determine the sulfur content and benzene content of the batch, as determined under § 80.1553(e) and (f), respectively.
(v) The RVP of the batch, reported to two decimal places, along with identification of the test method used to determine the RVP of the batch, as determined under § 80.1553(g). Documentation from the certified natural gasoline ethanol flex fuel blendstock refiner may be used to satisfy the requirement of this paragraph. In lieu of using a procedure specified in § 80.1553(g), if the RVP of the batch is less than atmospheric pressure as evidenced by its storage/handling procedures, a natural gasoline ethanol flex fuel blendstock refiner or natural gasoline ethanol flex fuel blendstock importer may report an RVP value of 15.0 psi for the batch.
(vi) The T90 distillation point and final distillation point temperatures of the batch reported to nearest whole degree F, along with identification of the test method used, as determined under § 80.1553(h). Documentation from the supplier of the natural gasoline used to produce certified natural gasoline ethanol flex fuel blendstock may be used to satisfy the requirement of this paragraph.
(vii) For each imported batch of certified natural gasoline ethanol flex fuel blendstock, the source refinery's EPA registration number.
(5) Certification that all batches of certified natural gasoline ethanol flex fuel blendstock produced or imported were compliant with the requirements of § 80.1524.
(d)
(1) Be signed and certified as meeting all of the applicable requirements of this subpart by the owner or a responsible corporate officer of the refiner or importer.
(2) Be submitted to EPA no later than the March 31 each year for the prior calendar year.
(3) All values measured or calculated pursuant to the requirements of this subpart shall be in accordance with the rounding procedure specified in § 80.1503.
(e)
Unless otherwise provided for in this section, the records required by this section shall be kept beginning on the compliance date specified in § 80.1504(b) and retained for a period of five years from the date of creation, and shall be delivered to the EPA Administrator or to the Administrator's authorized representative upon request.
(a)
(1) The product transfer document information required under § 80.1563.
(2) The date each batch was produced or imported.
(3) The batch volume.
(4) For each batch, all of the following information for any sampling and testing for sulfur content, benzene content, and RVP required under this subpart:
(i) The location, date, time, and storage tank or truck identification for each sample collected.
(ii) The name and title of the person who collected the sample and the person who performed the test.
(iii) The results of the test as originally printed by the testing apparatus, or where no printed result is produced, the results as originally recorded by the person who performed the test.
(iv) Any record that contains a test result for the sample that is not identical to the result recorded under paragraph (a)(4)(iii) of this section.
(v) The test methodology used.
(5) The batch number assigned under § 80.1521(g) and the appropriate designation under paragraph (a)(9) of this section.
(6) A copy of all registration records submitted to EPA under § 80.1550.
(7) A copy of all reports submitted to EPA under § 80.1551.
(8) Any calculations used to determine compliance with the applicable benzene content, sulfur content, and RVP standards of §§ 80.1520 and 80.1521.
(9) If appropriate, the designation of the batch as exempt ethanol flex fuel for national security purposes under § 80.1555, exempt ethanol flex fuel for research and development under § 80.1556, exempt ethanol flex fuel used in American Samoa, Guam, and the Commonwealth of the Northern Mariana Islands under § 80.1557, California ethanol flex fuel that meets the requirements of § 80.1558, or for export outside the United States.
(10) Bills of lading, invoices, certificates of analysis, and other commercial documents relating to the blendstocks used to produce the batch.
(11) For each batch of uncertified natural gasoline ethanol flex fuel used during the calendar year to produce ethanol flex fuel:
(i) The RVP of the batch, along with identification of the test method used, as determined under § 80.1553(g).
(ii) The T90 distillation point and final distillation point temperatures, along with identification of the test method used, as determined under § 80.1553(h).
(iii) Documentation from the supplier of the natural gasoline used by the ethanol flex fuel full-refiner or importer as uncertified natural gasoline ethanol flex fuel blendstock that demonstrates the uncertified natural gasoline ethanol flex fuel blendstock was produced from a processing unit (
(iv) Documentation from the supplier of the natural gasoline used by the ethanol flex fuel full-refiner or importer as uncertified natural gasoline ethanol flex fuel blendstock may be used to satisfy the requirements in paragraphs (a)(11)(i) and (a)(11)(ii) of this section.
(b)
(1)
(ii) The product transfer document information required under § 80.1610 for any DFE used to producer ethanol flex fuel.
(iii) Any product transfer document information for gasoline used to produce ethanol flex fuel, as required under § 80.77, § 80.106, § 80.210, § 80.219, § 80.1563, and/or § 80.1651.
(2) The date each batch was produced.
(3) The batch volume.
(4) In cases where natural gasoline ethanol flex fuel blendstock is used to produce ethanol flex fuel, the test or modeling results on the RVP of each batch and the test methodology used.
(5) For each batch, documentation concerning the composition of the ethanol flex fuel, including:
(i) The volume or concentration of the ethanol blend component as described in § 80.1522(b)(1).
(ii) The volume or concentration of any gasoline, CBOB, or RBOB blending component(s), as described in § 80.1522(b)(2) and (b)(3).
(iii) The volume or concentration of any natural gasoline ethanol flex fuel blendstock as described in § 80.1522(b)(4).
(iv) The type and amount of any ethanol flex fuel additives as described in § 80.1522(b)(5).
(v) Bills of lading, invoices, certificates of analysis, and other commercial documents relating to the blendstocks used to produce the batch.
(6) The batch number assigned under § 80.1522(d) and the appropriate designation under paragraph (b)(10) of this section.
(7) A copy of all registration records submitted to EPA under § 80.1550.
(8) A copy of all reports submitted to EPA under § 80.1551.
(9) Records related to the participation in a survey program under § 80.1561 or § 80.1562, as applicable.
(10) If appropriate, the designation of the batch as exempt ethanol flex fuel for national security purposes under § 80.1555, exempt ethanol flex fuel for research and development under § 80.1556, exempt ethanol flex fuel used in American Samoa, Guam, and the Commonwealth of the Northern Mariana Islands under § 80.1557, California ethanol flex fuel that meets the requirements of § 80.1558, or for export outside the United States.
(c)
(1) The product transfer document information required under § 80.1563 for the ethanol flex fuel used as a blendstock to produce ethanol flex fuel at a blender pump.
(2) Any product transfer document information for gasoline used to produce ethanol flex fuel, as required under § 80.77, § 80.106, § 80.210, § 80.219, § 80.1563, and/or § 80.1651.
(3) Records related to the participation in a survey program under § 80.1561 or § 80.1562, as applicable.
(4) Records related to any quality control program, including any calibration or certification required by a federal, state, or local government entity, conducted by the blender pump-refiner.
(5) Bills of lading, invoices, certificates of analysis, and other commercial documents relating to any parent blend used to produce ethanol flex fuel.
(d)
(1) The product transfer document information required under § 80.1563.
(2) The date each batch was produced.
(3) The batch volume.
(4) The sulfur content, benzene content, and RVP of the batch, as determined pursuant to the requirements of § 80.1553, as applicable. For batches reporting an RVP value of 15.0 pursuant to § 80.1551(c)(4)(v), the storage/handling procedures demonstrating an RVP less than atmospheric pressure.
(5) All of the following information for any sampling and testing for sulfur content, benzene content, and RVP required under this subpart:
(i) The location, date, time, and storage tank or truck identification for each sample collected.
(ii) The name and title of the person who collected the sample and the person who performed the test.
(iii) The results of the test as originally printed by the testing apparatus, or where no printed result is produced, the results as originally recorded by the person who performed the test.
(iv) Any record that contains a test result for the sample that is not identical to the result recorded under paragraph (d)(5)(iii) of this section.
(v) The test methodology used.
(6) The batch number assigned under § 80.1524(g).
(7) Documentation from the supplier of the natural gasoline used to produce certified natural gasoline ethanol flex fuel blendstock that demonstrates the certified natural gasoline ethanol flex fuel blendstock was produced from a
(8) A copy of all registration records submitted to EPA under § 80.1550.
(9) A copy of all reports submitted to EPA under § 80.1551.
(10) Bills of lading, invoices, certificates of analysis, and other commercial documents relating to the natural gasoline used to produce certified natural gasoline ethanol flex fuel blendstock.
(11) For each imported batch of certified ethanol flex fuel blendstock, the source refinery's EPA registration number.
(e)
(f)
(g)
(1) The product transfer document information for each batch.
(2) The date each batch was produced or imported.
(3) The batch volume.
(4) The maximum recommended treatment rate.
(5) Records of the additive manufacturer's control practices that demonstrate that the additive will contribute no more than 3 ppm on a per-gallon basis to the sulfur content of ethanol flex fuel when used at the maximum recommended treatment rate.
(h)
The sampling methods and test methods specified in this section shall be used to collect and test samples of ethanol flex fuel produced by ethanol flex fuel full-refiners, ethanol flex fuel importers, and ethanol flex fuel bulk blender-refiners pursuant to the requirements of §§ 80.1520, 80.1521 and 80.1522, and certified natural gasoline ethanol flex fuel blendstock produced by certified natural gasoline ethanol flex fuel blendstock refiners and certified natural gasoline ethanol flex fuel blendstock importers pursuant to the requirements of § 80.1524, for purposes of determining compliance with the requirements of this subpart.
(a)
(b)
(c)
(d)
(e)
(1) ASTM D2622.
(2) ASTM D1266, ASTM D3120, ASTM D5453, ASTM D6920, ASTM D7220, or ASTM D7039, provided the test result is correlated with the method specified in paragraph (e)(1) of this section.
(f)
(1) ASTM D5769.
(2) ASTM D5580, ASTM D3606, or ASTM D6730, provided the test result is correlated with the method specified in paragraph (f)(1) of this section.
(g)
(1) ASTM D5191.
(2) ASTM D5482 or ASTM D6378, provided the test result is correlated with the method specified in paragraph (g)(1) of this section.
(h)
(1) ASTM D86.
(2) [Reserved]
(i)
(1) ASTM D5599.
(2) ASTM D4815, provided the test result is correlated with the method specified in paragraph (i)(1) of this section.
(j)
(1)
(ii) The RVP of the CBOB, RBOB, E0, certified natural gasoline ethanol flex fuel blendstock, and/or ethanol denaturant hydrocarbon blend components used to produce the ethanol flex fuel shall be volume weighted to arrive at a RVP of the mixture of the hydrocarbon blend components. In cases where denatured fuel ethanol is used as a blending component, the denaturant concentration in the denatured fuel ethanol may be assumed to be 3 volume percent and the RVP of the denaturant to be 15.0 psi.
(iii) The volume weighted RVP of the mixture of the hydrocarbon blend components determined pursuant to the requirements of paragraph (j)(1)(ii) of this section shall be used in determining the RVP of the finished ethanol flex fuel blend using the RVP equations described in paragraph (j)(1)(iv) of this section.
(iv) RVP equations: RVP expressed in pounds per square inch (psi).
(2) [Reserved]
(a) Beginning on the date specified in § 80.1504(b), any ethanol flex fuel refiner, ethanol flex fuel importer, certified natural gasoline ethanol flex fuel blendstock refiner, or certified natural gasoline ethanol flex fuel blendstock importer shall:
(1) Retain a representative sample portion of each sample collected under § 80.1553, of at least 330 mL in volume.
(2) Retain such sample portions for the most recent 20 samples collected, or for each sample collected during the most recent 21 day period, whichever is greater, not to exceed 90 days for any given sample.
(3) Comply with the ethanol flex fuel or natural gasoline ethanol flex fuel blendstock sample handling procedures under § 80.1553(c) for each sample portion retained.
(4) Comply with any request by EPA to:
(i) Provide a retained sample portion to the Administrator's authorized representative.
(ii) Ship a retained sample portion to EPA, within two working days of the date of the request, by an overnight shipping service or comparable means, to the address and following procedures specified by EPA, and accompanied with the sulfur, benzene, RVP, and distillation test result for the sample determined pursuant to § 80.1553.
(b) [Reserved]
(a) The ethanol flex fuel standards of § 80.1520 do not apply to ethanol flex fuel that is produced, imported, sold, offered for sale, dispensed, supplied, offered for supply, stored, or transported for use in any of the following:
(1) Tactical military vehicles, engines, or equipment having an EPA national security exemption from the gasoline emission standards under 40 CFR part 86.
(2) Tactical military vehicles, engines, or equipment that are not subject to a national security exemption from vehicle or engine emissions standards as described in paragraph (a)(1) of this section but, for national security purposes (for purposes of readiness for deployment overseas), need to be fueled on the same ethanol flex fuel as the vehicles, engines, or equipment for which EPA has granted such a national security exemption.
(b) The exempt fuel must meet all the following conditions:
(1) It must be accompanied by product transfer documents as required under § 80.1563.
(2) It must be segregated from non-exempt ethanol flex fuel at all points in the distribution system.
(3) It must be dispensed from a fuel pump stand, fueling truck, or tank that is labeled with the appropriate designation of the fuel.
(4) It may not be used in any vehicles, engines, or equipment other than those referred to in paragraph (a) of this section.
(c) Any national security exemptions approved under subparts H and O of this part will remain in place under this subpart.
(a)
(b)
(1) Demonstrate a purpose that constitutes an appropriate basis for exemption.
(2) Demonstrate that an exemption is necessary.
(3) Design a R&D program that is reasonable in scope.
(4) Have a degree of control consistent with the purpose of the program and EPA's monitoring requirements.
(c)
(1) A concise statement of the purpose of the program demonstrating that the program has an appropriate R&D purpose.
(2) An explanation of why the stated purpose of the program cannot be achieved in a practicable manner without performing one or more of the prohibited acts under this subpart.
(3) A demonstration of the reasonableness of the scope of the program, including all of the following:
(i) An estimate of the program's beginning and ending dates.
(ii) An estimate of the maximum number of vehicles or engines involved in the program and the number of miles and engine hours that will be accumulated on each.
(iii) The sulfur content, benzene content, and RVP of the ethanol flex fuel expected to be used in the program.
(iv) The quantity of ethanol flex fuel that does not comply with the requirements of § 80.1520.
(v) The manner in which the information on vehicles and engines used in the program will be recorded and made available to the Administrator upon request.
(4) With regard to control, a demonstration that the program affords EPA a monitoring capability, including all the following:
(i) A description of the technical and operational aspects of the program.
(ii) The site(s) of the program (including facility name, street address, city, county, state, and zip code).
(iii) The manner in which information on the fuel used in the program (including quantity, fuel properties, name, address, telephone number and contact person of the supplier, and the date received from the supplier), will be recorded and made available to the Administrator upon request.
(iv) The manner in which the party will ensure that the R&D fuel will be segregated from ethanol flex fuel meeting the standards of this subpart and how fuel pumps will be labeled to ensure proper use of the R&D fuel.
(v) The name, address, telephone number, and title of the person(s) in the organization requesting an exemption from whom further information on the application may be obtained.
(vi) The name, address, telephone number, and title of the person(s) in the organization requesting an exemption who is responsible for recording and making available the information specified in this paragraph (c), and the location where such information will be maintained.
(d)
(2) The R&D ethanol flex fuel must be designated by the refiner or supplier, as
(3) The R&D ethanol flex fuel must be kept segregated from non-exempt ethanol flex fuel at all points in the distribution system.
(4) The R&D ethanol flex fuel must not be sold, distributed, offered for sale or distribution, dispensed, supplied, offered for supply, transported to or from, or stored by a fuel retail outlet, or by a wholesale purchaser-consumer facility, unless the wholesale purchaser-consumer facility is associated with the R&D program that uses the ethanol flex fuel.
(5) At the completion of the program, any emission control systems or elements of design which are damaged or rendered inoperative shall be replaced on vehicles remaining in service, or the responsible person will be liable for a violation of the Clean Air Act section 203(a)(3) (42 U.S.C. 7522(a)(3)) unless sufficient evidence is supplied that the emission controls or elements of design were not damaged.
(e)
(1) The volume of fuel subject to the approval shall not exceed the estimated amount under paragraph (c)(3) of this section, unless EPA grants a greater amount in writing.
(2) Any exemption granted under this section will expire at the completion of the test program or three years from the date of approval, whichever occurs first, and may only be extended upon re-application consistent will all requirements of this section.
(3) EPA may elect at any time to review the information contained in the request, and where appropriate may notify the responsible person of disapproval of the exemption.
(4) In granting an exemption the Administrator may include terms and conditions, including replacement of emission control devices or elements of design, which the Administrator determines are necessary for monitoring the exemption and for assuring that the purposes of this subpart are met.
(5) Any violation of a term or condition of the exemption, or of any requirement of this section, will cause the exemption to be void ab initio.
(6) If any information required under paragraph (c) of this section should change after approval of the exemption, the responsible person must notify EPA in writing immediately. Failure to do so may result in disapproval of the exemption or may make it void ab initio, and may make the party liable for a violation of this subpart.
(f)
(g)
(h)
The ethanol flex fuel standards of this subpart do not apply to ethanol flex fuel that is produced, imported, sold, offered for sale, dispensed, supplied, offered for supply, stored, or transported for use in the Territories of Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands, provided that such ethanol flex fuel meets all the following requirements:
(a) The ethanol flex fuel is designated by the ethanol flex fuel refiner or ethanol flex fuel importer as ethanol flex fuel only for use in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands.
(b) The ethanol flex fuel is used only in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands.
(c) The ethanol flex fuel is accompanied by documentation that complies with the product transfer document requirements of § 80.1563.
(d) The ethanol flex fuel is segregated from non-exempt ethanol flex fuel at all points in the distribution system from the point the fuel is designated as ethanol flex fuel only for use in Guam, American Samoa, or the Commonwealth of the Northern Mariana Islands, while the fuel is in the United States but outside these Territories.
(a)
(b)
(2) Designated California ethanol flex fuel must be kept segregated from ethanol flex fuel that is not California ethanol flex fuel at all points in the distribution system.
(3) Designated California ethanol flex fuel must ultimately be dispensed into flex-fuel vehicles and engines in the State of California for their use.
(4) For California ethanol flex fuel produced outside the State of California, the transferors and transferees must meet the product transfer document requirements of paragraph (b)(5) of this section.
(5)(i) Any refiner that operates a refinery located outside the State of California at which California ethanol flex fuel is produced must provide to any person to whom custody or title of such gasoline has transferred, and each transferee must provide to any subsequent transferee, documents that include all the following information:
(A) The name and address of the transferor.
(B) The name and address of the transferee.
(C) The volume of ethanol flex fuel which is being transferred.
(D) The location of the ethanol flex fuel at the time of the transfer.
(E) The date and time of the transfer.
(F) The identification of the ethanol flex fuel as California ethanol flex fuel.
(ii) Each refiner and transferee of California ethanol flex fuel must maintain copies of the product transfer documents required to be provided by paragraph (b)(5)(i) of this section for a period of five years from the date of creation and shall deliver such documents to the Administrator or to the Administrator's authorized representative upon request.
(6) Ethanol flex fuel that is ultimately used or dispensed in any part of the United States outside of the State of California must comply with the standards of § 80.1520 and any associated applicable requirements, regardless of any designation as California ethanol flex fuel.
(b) * * *
(3) * * *
(ii)(A) Obtain samples of gasoline offered for sale at gasoline retail outlets in accordance with the survey program plan approved under this paragraph (b), or immediately notify EPA of any refusal of retail outlets to allow samples to be taken.
(B) Samples of E15 collected from blender pump-refineries shall be collected using a method specified in
(iii) Test, or arrange to be tested, the samples required under paragraph (b)(3)(ii) of this section for RVP and oxygenate content as follows:
(v) Confirm that each fuel dispenser sampled is labeled as required in § 80.1502 by confirming that:
(A) The label meets the appearance and content requirements of § 80.1502.
(B) The label is located on the fuel dispenser according to the requirements in § 80.1502.
(c) * * *
(4) The survey program plan must be sent to the attention of “E15 Survey Program Plan” to the address in § 80.10(a).
(d) * * *
(3) For the first year in which a survey program will be conducted, no later than 15 days preceding the start of the survey EPA must receive a copy of the contract with the independent surveyor and proof that the money necessary to carry out the survey plan has either been paid to the independent surveyor or placed into an escrow account; if the money has been placed into an escrow account, a copy of the escrow agreement must be sent to the official designated in paragraph (c)(4) of this section.
(e)
(a)
(2)
(i) Planned and conducted by a survey association that is independent of the ethanol flex fuel bulk blender-refiner and blender pump-refiners that arrange to have the survey conducted. In order to be considered independent, all of the following conditions must be met:
(A) Representatives of the survey association shall not be an employee of any ethanol flex fuel bulk blender-refinery or blender pump-refiner.
(B) The survey association shall be free from any obligation to or interest in any ethanol flex fuel bulk blender-refinery or blender pump-refiner.
(C) The ethanol flex fuel bulk blender-refinery and blender pump-refiners that arrange to have the survey conducted shall be free from any obligation to or interest in the survey association.
(ii) Conducted separately at all ethanol flex fuel retail stations and at a subset of blender pump-refineries.
(iii) Represent all ethanol flex fuel retail stations and blender pump-refineries that dispense ethanol flex fuel nationwide.
(3)
(i) Submit to EPA for approval each calendar year a proposed survey program plan in accordance with the requirements of paragraph (a)(4) of this section.
(ii)(A) Obtain samples representative of the ethanol flex fuel offered for sale separately from all ethanol flex fuel stations and the subset of blender pump-refineries in accordance with the survey program plan approved by EPA, or immediately notify EPA of any refusal of blender pump-refineries or ethanol flex fuel retail stations that operate blender pumps to allow samples to be taken.
(B) Samples of ethanol flex fuels collected from blender pump-refineries shall be collected using a method specified in
(iii) Test, or arrange to be tested, the samples required under paragraph (a)(3)(ii) of this section for oxygenate content, sulfur content, benzene content, and RVP (from June 1 through September 15), as follows:
(A) Samples collected shall be shipped the same day the samples are collected via ground service to the laboratory and analyzed for oxygenate content, sulfur content, benzene content, and RVP. Such analysis shall be completed within 10 days after receipt of the sample in the laboratory.
(B) Any laboratory to be used by the independent survey association for oxygenate content, sulfur content, benzene content, or RVP testing shall be approved by EPA and its test method for determining oxygenate content, sulfur content, benzene content, and RVP shall be an appropriate method as described in § 80.1553(e) through (i).
(iv) In the case of any test that yields a result that a sample potentially exceeds the 95 ppm sulfur standard of § 80.1520(b)(1)(ii)(B) or applicable RVP standard of § 80.1520(c), the independent survey association shall, within 24 hours after the laboratory has completed analysis of the sample, send notification of the test result as follows:
(A) In the case of a sample collected at a blender pump-refinery at which the brand name of a refiner or importer is displayed, to the ethanol flex fuel refiner or ethanol flex fuel importer, and EPA. This initial notification to the ethanol flex fuel refiner or ethanol flex fuel importer shall include specific information concerning the name and address of the blender pump-refinery or ethanol flex fuel retail station, contact information, the brand, and the sulfur content and/or RVP of the sample.
(B) In the case of a sample collected at any other blender pump-refineries or ethanol flex fuel retail stations, to the ethanol flex fuel bulk blender-refiner or blender pump-refiner and EPA, and such notice shall contain the same information as in paragraph (a)(3)(iv)(A) of this section.
(C) The independent survey association shall provide notice to the identified contact person or persons for each party in writing (which includes email or facsimile) and, if requested by the identified contact person, by telephone.
(v) Provide to EPA quarterly and annual summary survey reports which include the information specified in paragraph (a)(5) of this section.
(vi) Maintain all records relating to the surveys conducted under this paragraph (a) for a period of at least five (5) years.
(vii) Permit any representative of EPA to monitor at any time the conducting of the surveys, including sample collection, transportation, storage, and analysis.
(4)
(i)
(A) One survey during the period of January 1 through March 31.
(B) One survey during the period of April 1 through June 30.
(C) One survey during the period of July 1 through September 30.
(D) One survey during the period of October 1 through December 31.
(ii)
(iii)
(B) In the case of any ethanol flex fuel blender pump-refinery or ethanol flex fuel retail station from which a sample of ethanol flex fuel was collected during a survey and determined to have a dispenser containing fuel whose sulfur content does not comply with the 95 ppm sulfur standard in § 80.1520(b)(1)(ii)(B) or whose RVP does not comply with the applicable RVP standard in § 80.1520(c), that blender pump-refinery or ethanol flex fuel retail station shall be included in the subsequent survey.
(C) At least one sample of a product dispensed as ethanol flex fuel shall be collected at each blender pump-refinery and ethanol flex fuel retail station, and separate samples must be taken that represent the gasoline or ethanol flex fuel contained in each storage tank, unless collection of separate samples is not practicable.
(iv)
(B) If the number of blender pump-refineries from participating blender pump-refiners or ethanol flex fuel retail stations is less than 500, the minimum number of samples to be included in the survey plan for each calendar year shall be sufficient to ensure that each blender pump-refinery or ethanol flex fuel retail station is sampled at least once during the calendar year.
(C) If the number of blender pump-refineries from participating blender pump-refiners or ethanol flex fuel retail stations is 500 or greater, the minimum number of samples to be included in the survey plan for each calendar year shall be calculated as follows:
(D) The number of samples determined pursuant to paragraphs (a)(4)(iv)(B) and (a)(4)(iv)(C) of this section, after being incremented as necessary to allocate whole numbers of samples to each cluster, shall be distributed approximately equally for the four surveys conducted during the calendar year.
(5)
(i) An identification of the parties that are participating in the survey.
(ii) The identification of each sampling area included in a survey and the dates that the samples were collected in that area.
(iii) For each retail blender pump-refinery and ethanol flex fuel retail station sampled:
(A) The identification of the blender pump-refinery or ethanol flex fuel retail station.
(B) The refiner or importer brand name displayed, if any.
(C) The fuel dispenser labeling (
(D) The sample test result for oxygenate content, sulfur content, benzene content, and RVP result, if any.
(E) The test method used to determine oxygenate content as described in § 80.1553(i).
(F) The test method used to determine sulfur content as described in § 80.1553(e).
(G) The test method used to determine benzene content as described in § 80.1553(f).
(H) The test method used to determine RVP as described in § 80.1553(g).
(iv) Ethanol level, sulfur content, benzene content, and RVP summary statistics by brand and unbranded for each sampling area and survey series. These summary statistics shall:
(A) Include the number of samples and the average, median, and range of: ethanol content, expressed in volume percent; sulfur content, expressed in parts per million; benzene content, expressed in volume percent; and RVP, expressed in pounds per square inch.
(B) [Reserved]
(v) The quarterly reports required under paragraph (a)(3)(v) of this section are due 60 days following the end of each survey period as described in paragraph (a)(4)(i) of this section. The annual reports required under paragraph (a)(3)(v) of this section are due 60 days following the end of the calendar year.
(vi) The reports required under this paragraph (a)(3)(v) shall be submitted to EPA in an electronic spreadsheet.
(b)
(2) The survey program plan must be signed by a responsible officer of the independent surveyor conducting the survey program.
(3) The survey program plan must be sent to the attention of “Ethanol Flex Fuel Survey Requirements” to the address in § 80.10(a).
(4) EPA will send a letter to the party submitting the survey program plan that indicates whether EPA approves or disapproves the survey plan.
(5) The approving official for a survey plan under this section is the Director of the Compliance Division, Office of Transportation and Air Quality.
(6) Any notifications or reports required to be submitted to EPA under this section must be directed to the official designated in paragraph (b)(5) of this section.
(c)
(2) No later than December 15 of the year preceding the year in which the survey will be conducted, EPA must receive a copy of the contract with the independent surveyor and proof that the money necessary to carry out the survey plan has either been paid to the independent surveyor or placed into an escrow account; if placed into an escrow account, a copy of the escrow agreement must be sent to the official designated in paragraph (b)(5) of this section.
(d)
(1) EPA may revoke its approval of a survey plan under this section for cause, including, but not limited to, an EPA determination that the approved survey plan has proved to be inadequate in practice.
(2) EPA may void
99. Newly redesignated § 80.1563 is amended by:
a. Revising the section heading;
b. Revising paragraphs (a)(1)(vi)(A) and (b)(1)(vi)(E); and
c. Redesignating paragraphs (c) and (d) as paragraphs (f) and (g) and adding new paragraphs (c) and (d) and paragraph (e).
The revisions and additions read as follows:
(a) * * *
(1) * * *
(vi) * * *
(A) The maximum RVP, as determined by an applicable method permitted under § 80.46, § 80.47, § 80.1553(g), or § 80.1553(j), stated in the following format: “The RVP of this gasoline does not exceed [fill in appropriate value].”; and
(b) * * *
(1) * * *
(vi) * * *
(E) For all ethanol flex fuels, the following statement: “Ethanol Flex Fuel—Contains XX% ethanol.” The term XX refers to the volume percent of ethanol present in the ethanol flex fuel.
(c)
(i) The name and address of the transferor.
(ii) The name and address of the transferee.
(iii) The volume of ethanol flex fuel being transferred.
(iv) The location of the ethanol flex fuel at the time of the transfer.
(v) The date of the transfer.
(vi) The concentration of ethanol pursuant to paragraph (b)(1)(vi)(E) of this section.
(vii) The type and volume of each hydrocarbon feedstock expressed in volume percent to the nearest whole number that was used to produce the ethanol flex fuel (
(viii) A statement that the ethanol flex fuel meets the applicable RVP standard.
(ix) A statement that the concentration of natural gasoline ethanol flex fuel blendstock blended in to produce ethanol flex fuel is less than or equal to 30 volume percent.
(2) [Reserved]
(d)
(i) The name and address of the transferor.
(ii) The name and address of the transferee.
(iii) The volume of certified natural gasoline ethanol flex fuel blendstock being transferred.
(iv) The location of the certified natural gasoline ethanol flex fuel blendstock at the time of the transfer.
(v) The date of the transfer.
(vi) The maximum RVP, as determined by an applicable method permitted under § 80.1553(g), or 15.0 psi as described § 80.1551(c)(4)(v).
(vii) Statement on the product transfer document as follows:
(A) For certified natural gasoline ethanol flex fuel blendstock that meet the requirements of § 80.1524, “Certified natural gasoline EFF blendstock—Suitable for use to manufacture ethanol flex fuels meeting EPA standards. Cannot be used as gasoline, CBOB, or RBOB.”
(B) [Reserved]
(2) [Reserved]
(e) Alternative product transfer document language to that specified in paragraphs (a) through (d) of this section may be used as approved by EPA.
The revisions and additions read as follows:
(a) * * *
(2) Manufacture or introduce into commerce E15 in any calendar year for use in an area prior to commencement of a survey approved under 80.1561 for that area.
(3) Sell, introduce, cause, or permit the sale or introduction of gasoline containing greater than 15 volume percent ethanol (
(4) Be prohibited from manufacturing, selling, introducing, causing, or allowing the sale or introduction of gasoline containing greater than 15 volume percent ethanol into any flex-fuel vehicle or flex-fuel engine, notwithstanding paragraphs (a)(1) through (3) of this section.
(b) Sell, offer for sale, dispense, or otherwise make available at a retail or wholesale purchaser-consumer facility E15 that is not correctly labeled in accordance with § 80.1502.
(c) Fail to fully or timely implement, or cause a failure to fully or timely implement, an approved survey required under § 80.1561 or § 80.1562.
(d) Fail to generate, use, transfer, and maintain product transfer documents that accurately reflect the type of product, ethanol content, maximum RVP, and other information required under § 80.1563.
(e) * * *
(1) Improperly blend, or cause the improper blending of, ethanol into conventional blendstock for oxygenate blending, gasoline, or gasoline already containing ethanol, in a manner inconsistent with the information on the product transfer document under § 80.1563(a)(1)(vi) or (b)(1)(vi).
(h) Produce, import, sell, offer for sale, dispense, supply, offer for supply, store, or transport ethanol flex fuel or certified natural gasoline ethanol flex fuel blendstock that does not comply with the applicable sulfur standards under § 80.1520(b)(1) or § 80.1524(b)(1).
(i) Cause ethanol flex fuel or certified natural gasoline ethanol flex fuel blendstock to be in the distribution system that does not comply with the applicable sulfur per-gallon cap standard under § 80.1520(b)(1)(ii) or § 80.1524(b)(1).
(j) Produce, import, sell, offer for sale, dispense, supply, offer for supply, store, or transport ethanol flex fuel or certified natural gasoline ethanol flex fuel blendstock that does not comply with the applicable benzene standards under § 80.1520(b)(2) or § 80.1524(c)(1).
(k) Cause certified natural gasoline ethanol flex fuel blendstock to be in the distribution system that does not comply with the applicable benzene per-gallon cap standard under § 80.1524(c)(1).
(l) Produce, import, sell, offer for sale, dispense, supply, offer for supply, store, or transport ethanol flex fuel or natural gasoline ethanol flex fuel blendstock that does not comply with the applicable carbon, hydrogen, oxygen, nitrogen, and sulfur elemental composition standard under § 80.1520(b)(3), § 80.1521(b)(5)(iii), or § 80.1524(f) without a waiver.
(m) Produce, import, sell, offer for sale, dispense, supply, offer for supply, store, or transport ethanol flex fuel or natural gasoline ethanol flex fuel blendstock that does not comply with the applicable RVP standard under § 80.1520(c), § 80.1521(b)(5)(i), or § 80.1524(d)(1).
(n) Cause ethanol flex fuel or natural gasoline ethanol flex fuel blendstock to be in the distribution system that does not comply with the applicable RVP standard under § 80.1520(c), § 80.1521(b)(5)(i), or § 80.1524(d)(1).
(o) Produce, import, sell, offer for sale, dispense, supply, offer for supply, store, or transport natural gasoline ethanol flex fuel blendstock that does not comply with the T90 distillation point or final distillation point standards under § 80.1521(b)(5)(ii) or § 80.1524(e)(1).
(p) Cause natural gasoline ethanol flex fuel blendstock to be in the distribution system that does not comply with the T90 distillation point or final distillation point standards under § 80.1521(b)(5)(iii) or § 80.1524(e)(1).
(q) Produce ethanol flex fuel at an ethanol flex fuel full-refinery pursuant to § 80.1521 with blendstocks that do not meet the certified natural gasoline ethanol flex fuel blendstock requirements in § 80.1524, the uncertified natural gasoline ethanol flex fuel blendstock requirements in § 80.1521(b)(5), the denatured fuel ethanol requirements in § 80.1610, the undenatured ethanol requirements in § 80.1521(b)(1)(ii), or the applicable gasoline, RBOB, and CBOB requirements in this part.
(r) Produce ethanol flex fuel at an ethanol flex fuel bulk blender-refinery pursuant to § 80.1522 with blendstocks that do not meet the certified natural gasoline ethanol flex fuel blendstock requirements in § 80.1524, the denatured fuel ethanol requirements in § 80.1610, the undenatured ethanol requirements in § 80.1522(b)(1)(ii), or the applicable gasoline, RBOB, and CBOB requirements in this part.
(s) Produce ethanol flex fuel at a blender pump-refinery pursuant to § 80.1523 with blendstocks other than ethanol flex fuel that meets the requirements of § 80.1520 or gasoline.
(t) Introduce an additive into ethanol flex fuel that contributes more than 3 ppm to the sulfur content of the finished ethanol flex fuel unless acting in the capacity of an ethanol flex fuel full-refiner or ethanol flex fuel importer under § 80.1521.
(u) Cause or contribute to the introduction into commerce of an additive intended to be used in ethanol flex fuel at less than 1 volume percent that does not comply with the requirements of § 80.1525.
(v) Sell, introduce, cause, or permit the sale or introduction of a gasoline-ethanol blended fuel containing greater than 83 volume percent ethanol into a flexible fuel vehicle certified under 40 CFR part 86 or flexible fuel engine
(w) Commingle separate batches of ethanol flex fuel except when separate batches of ethanol flex fuel are commingled in a storage tank at an ethanol flex fuel retail station or wholesale purchaser-consumer facility.
(x) Add any hydrocarbon or ethanol blendstock to previously certified ethanol flex fuel.
(z) Cause another person to commit an act in violation of paragraphs (a) through (y) of this section.
(a)
(1) Each gasoline refiner, gasoline importer, oxygenate blender, ethanol flex fuel refiner, ethanol flex fuel importer, natural gasoline ethanol flex fuel blendstock refiner, natural gasoline ethanol flex fuel blendstock importer, carrier, distributor, reseller, retailer, or wholesale purchaser-consumer who owns, leases, operates, controls, or supervises the facility where the violation is found.
(2) Each gasoline refiner, gasoline importer, ethanol flex fuel refiner, ethanol flex fuel importer, natural gasoline ethanol flex fuel blendstock refiner, or natural gasoline ethanol flex fuel blendstock importer whose corporate, trade, or brand name, or whose marketing subsidiary's corporate, trade, or brand name, appears at the facility where the violation is found.
(3) Each gasoline refiner, gasoline importer, oxygenate blender, ethanol flex fuel refiner, ethanol flex fuel importer, natural gasoline ethanol flex fuel blendstock refiner, natural gasoline ethanol flex fuel blendstock importer, distributor, or reseller who manufactured, imported, sold, offered for sale, dispensed, supplied, offered for supply, stored, transported, or caused the transportation of any gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock that is in the storage tank containing gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock found to be in violation.
(4) Each carrier who dispensed, supplied, stored, or transported any gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock that is in the storage tank containing gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock found to be in violation, provided that EPA demonstrates, by reasonably specific showings using direct or circumstantial evidence, that the carrier caused the violation.
(b) For label violations under § 80.1564(b), only the wholesale purchaser-consumer or retailer and the branded gasoline refiner, branded gasoline importer, branded ethanol flex fuel refiner, or branded ethanol flex fuel importer, if any, shall be liable.
(a) Any person under § 80.1565 who is liable for a violation under § 80.1564 is subject to an administrative or civil penalty, as specified in Clean Air Act sections 205 and 211(d), for every day of each such violation and the amount of economic benefit or savings resulting from the violation.
(a) * * *
(1) In any case in which a gasoline refiner, gasoline importer, oxygenate blender, ethanol flex fuel refiner, ethanol flex fuel importer, natural gasoline ethanol flex fuel blendstock refiner, natural gasoline ethanol flex fuel blendstock importer, carrier, distributor, reseller, retailer, or wholesale purchaser-consumer would be in violation under § 80.1564(a) and (c) through (z) it shall be deemed not in violation if it can demonstrate:
(ii) That product transfer documents account for all of the gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock in the storage tank found in violation and indicate that the gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock met relevant requirements; and
(iii) * * *
(B) A carrier may rely on the sampling and testing program carried out by another party, including the party that owns the gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock in question, provided that the sampling and testing program is carried out properly.
(2) * * *
(i) * * *
(B) The action of any reseller, distributor, oxygenate blender, ethanol flex fuel bulk blender-refiner, blender pump-refiner, carrier, or a retailer or wholesale purchaser-consumer supplied by any of these persons, in violation of a contractual agreement imposed by the gasoline refiner or ethanol flex fuel refiner designed to prevent such action, and despite periodic sampling and testing by the gasoline refiner or ethanol flex fuel refiner to ensure compliance with such contractual obligation; or
(C) The action of any carrier or other distributor not subject to a contract with the gasoline refiner or ethanol flex fuel refiner but engaged by the gasoline refiner or ethanol flex fuel refiner for transportation of gasoline or ethanol flex fuel, despite specification or inspection of procedures and equipment by the gasoline refiner or ethanol flex fuel refiner that are reasonably calculated to prevent such action.
(3) For label violations under § 80.1564(b), the branded gasoline refiner, branded gasoline importer, branded ethanol flex fuel refiner, or branded ethanol flex fuel importer shall not be deemed liable if the requirements of paragraph (b)(4) of this section are met.
(b)
(1)(i) For gasoline, a periodic sampling and testing program to determine if the gasoline contains applicable maximum and minimum volume percent of ethanol.
(ii) For ethanol flex fuel or natural gasoline ethanol flex fuel blendstock, a periodic sampling and testing program to determine if the ethanol flex fuel or natural gasoline ethanol flex fuel blendstock meets the applicable maximum sulfur content standard and RVP standard.
(2) That on each occasion when gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock is found in noncompliance with one of the requirements referred to in paragraph (b)(1) of this section:
(3) An oversight program conducted by a carrier under paragraph (b)(1) or (b)(2) of this section need not include periodic sampling and testing of gasoline, ethanol flex fuel, and natural gasoline ethanol flex fuel blendstock in a tank truck operated by a common carrier, but in lieu of such tank truck sampling and testing the common carrier shall demonstrate evidence of an oversight program for monitoring compliance with the requirements of § 80.1564 relating to the transport or storage of gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock by tank truck, such as appropriate guidance to drivers on compliance with applicable requirements and the periodic review of records normally received in the ordinary course of business concerning gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock quality and delivery.
(4) The periodic sampling and testing program specified in paragraph (b)(1) or (b)(2) of this section shall be deemed to have been in effect during the relevant time period for any party, including branded gasoline refiners, branded gasoline importers, branded ethanol flex fuel importers, and branded ethanol flex fuel refiners if:
(i) An EPA approved survey program under § 80.1561 or § 80.1562 was in effect and was implemented fully and properly;
The revision and additions read as follows:
(a) Compliance with the ethanol content of gasoline or ethanol flex fuel shall be determined based on the ethanol content of the gasoline or ethanol flex fuel measured or otherwise determined, as applicable, using any of the applicable methodologies specified in § 80.46, § 80.47, or § 80.1553. Any evidence or information, including the exclusive use of such evidence or information, may be used to establish the ethanol content of the gasoline or ethanol flex fuel if the evidence or information is relevant to whether the ethanol content of the gasoline or ethanol flex fuel would have been in compliance with the standard if the appropriate sampling and testing methodologies had been correctly performed. Such evidence may be obtained from any source or location and may include, but is not limited to, test results using methods other than those specified in §§ 80.46, 80.47, and 80.1553, business records, and commercial documents.
(b) Compliance with the sulfur standards of this subpart shall be determined based on the sulfur content of the gasoline, denatured fuel ethanol, oxygenate, ethanol flex fuel, or certified natural gasoline ethanol flex fuel blendstock measured or otherwise determined, as applicable, using any of the applicable methodologies specified in § 80.46, § 80.47, or § 80.1553. Any evidence or information, including the exclusive use of such evidence or information, may be used to establish the sulfur content of the gasoline, denatured fuel ethanol, oxygenate, ethanol flex fuel, or certified natural gasoline ethanol flex fuel blendstock if the evidence or information is relevant to whether the sulfur content of the gasoline, denatured fuel ethanol, oxygenate, ethanol flex fuel, or certified natural gasoline ethanol flex fuel blendstock would have been in compliance with the standards if the appropriate sampling and testing methodologies had been correctly performed. Such evidence may be obtained from any source or location and may include, but is not limited to, test results using methods other than those specified in §§ 80.46, 80.47, and 80.1553, business records, and commercial documents.
(c) Compliance with the benzene standards of this subpart shall be determined based on the benzene content of the gasoline, ethanol flex fuel, or certified natural gasoline ethanol flex fuel blendstock measured or otherwise determined, as applicable, using any of the applicable methodologies specified in § 80.46, § 80.47, or § 80.1553. Any evidence or information, including the exclusive use of such evidence or information, may be used to establish the benzene content of the gasoline, ethanol flex fuel, or certified natural gasoline ethanol flex fuel blendstock if the evidence or information is relevant to whether the benzene content of the gasoline, ethanol flex fuel, or certified natural gasoline ethanol flex fuel blendstock would have been in compliance with the standard if the appropriate sampling and testing methodologies had been correctly performed. Such evidence may be obtained from any source or location and may include, but is not limited to, test results using methods other than those specified in §§ 80.46, 80.47, and 80.1553, business records, and commercial documents.
(d) Compliance with the RVP standards of this subpart shall be determined based on the maximum psi of the gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock measured or otherwise determined, as applicable, using any of the applicable methodologies specified in § 80.46, § 80.47, or § 80.1553. Any evidence or information, including the exclusive use of such evidence or information, may be used to establish the RVP of the gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock if the evidence or information is relevant to whether the RVP of the gasoline, ethanol flex fuel, or natural gasoline ethanol flex fuel blendstock would have been in compliance with the standard if the appropriate sampling and testing methodologies had been correctly performed. Such evidence may be obtained from any source or location and may include, but is not limited to, test results using methods other than those specified in §§ 80.46, 80.47, and 80.1553, business records, and commercial documents.
(e) Compliance with the T90 distillation point and final distillation point standards of this subpart for natural gasoline ethanol flex fuel blendstock shall be determined based on the maximum degrees Celsius of the natural gasoline ethanol flex fuel blendstock measured or otherwise determined, as applicable, using any of the applicable methodologies specified in § 80.46, § 80.47, or § 80.1553. Any evidence or information, including the exclusive use of such evidence or information, may be used to establish the T90 distillation point and final distillation point of the natural gasoline
In addition to the requirements for attest engagements that apply to refiners and importers under §§ 80.125 through 80.130, 80.1666, and other sections of this part, the following annual attest engagement procedures are required under this subpart.
(a)
(b)
(2) Agree the yearly volume reported to EPA with the inventory reconciliation analysis under the attest engagement provisions of § 80.128.
(3) Calculate the annual average sulfur level and annual average benzene level for all ethanol flex fuel and agree those values with the values reported to EPA.
(4) Agree the information in the ethanol flex fuel full-refiner's or importer's batch reports filed with EPA under § 80.1551(a), and any laboratory test results, with the information contained in the annual report required under § 80.1551(a).
(5) Reports as a finding any discrepancies identified in paragraphs (b)(1) through (4) of this section in the attest engagement report submitted to the EPA under § 80.130.
(c)
(2) Agree the yearly volume reported to EPA with the inventory reconciliation analysis under the attest engagement provisions of § 80.128.
(3) Agree the information in the certified natural gasoline ethanol flex fuel blendstock refiner's or certified natural gasoline ethanol flex fuel blendstock importer's batch reports filed with EPA under § 80.1551(c), and any laboratory test results, with the information contained in the annual report required under § 80.1551(c).
(4) Report as a finding any discrepancies identified in paragraphs (c)(1) through (3) of this section in the attest engagement report submitted to the EPA under § 80.130.
(d)
(2) Agree the yearly volume reported to EPA with the inventory reconciliation analysis under the attest engagement provisions of § 80.128.
(3) Calculate the total volume of ethanol flex fuel blended, and agree those values with the values reported to EPA.
(4) Agree the information in the ethanol flex fuel bulk blender-refiners batch reports filed with EPA under § 80.1551(b), and any laboratory test results, with the information contained in the annual report required under § 80.1551(b).
(5) Report as a finding any discrepancies identified in paragraphs (d)(1) through (4) of this section in the attest engagement report submitted to the EPA under § 80.130.
The published materials identified in this section are incorporated by reference into this subpart with the approval of the Director of the
(a)
(1) ASTM D4057-12, Standard Practice for Manual Sampling of Petroleum and Petroleum Products, approved December 1, 2012.
(2) ASTM D4177-95 (Reapproved 2010), Standard Practice for Automatic Sampling of Petroleum and Petroleum Products, approved May 1, 2010.
(3) ASTM D5842-14, Standard Practice for Sampling and Handling of Fuels for Volatility Measurement, approved July 1, 2009.
(4) ASTM D5854-96 (Reapproved 2010), Standard Practice for Mixing and Handling of Liquid Samples of Petroleum and Petroleum Products, approved May 1, 2010.
(5) ASTM D2622-10, Sulfur Test Method for Sulfur in Petroleum Products by Wavelength Dispersive X-ray Fluorescence Spectrometry, approved February 15, 2010.
(6) ASTM D1266-13, Sulfur Test Method for Sulfur in Petroleum Products (Lamp Method), approved June 15, 2013.
(7) ASTM D3120-08 (Reapproved 2014), Standard Test Method for Trace Quantities of Sulfur in Light Liquid Petroleum Hydrocarbons by Oxidative
(8) ASTM D5453-12, Standard Test Method for Determination of Total Sulfur in Light Hydrocarbons, Spark Ignition Engine Fuel, Diesel Engine Fuel, and Engine Oil by Ultraviolet Fluorescence, approved November 1, 2012.
(9) ASTM D6920-13, Standard Test Method for Total Sulfur in Naphthas, Distillates, Reformulated Gasolines, Diesels, Biodiesels, and Motor Fuels by Oxidative Combustion and Electrochemical Detection, approved September 15, 2013.
(10) ASTM D7220-12, Standard Test Method for Sulfur in Automotive, Heating, and Jet Fuels by Monochromatic Energy Dispersive X-ray Fluorescence Spectrometry, approved June 15, 2012.
(11) ASTM D7039-13, Standard Test Method for Sulfur in Gasoline, Diesel Fuel, Jet Fuel, Kerosine, Biodiesel, Biodiesel Blends, and Gasoline-Ethanol Blends by Monochromatic Wavelength Dispersive X-ray Fluorescence Spectrometry, approved September 15, 2013.
(12) ASTM D5769, Standard Test Method for Determination of Benzene, Toluene, and Total Aromatics in Finished Gasolines by Gas Chromatography/Mass Spectrometry, approved May 1, 2010.
(13) ASTM D5580-13, Standard Test Method for Determination of Benzene, Toluene, Ethylbenzene, p/m-Xylene, o-Xylene, C9 and Heavier Aromatics, and Total Aromatics in Finished Gasoline by Gas Chromatography, approved September 15, 2013.
(14) ASTM D3606, Standard Test Method for Determination of Benzene and Toluene in Finished Motor and Aviation Gasoline by Gas Chromatography, approved October 1, 2010.
(15) ASTM D6730-01 (Reapproved 2011), Standard Test Method for Determination of Individual Components in Spark Ignition Engine Fuels by 100-Metre Capillary (with Precolumn) High-Resolution Gas Chromatography, approved May 1, 2011.
(16) ASTM D5191-13, Standard Test Method for Vapor Pressure of Petroleum Products (Mini Method), approved December 1, 2013.
(17) ASTM D5482-07 (Reapproved 2013), Standard Test Method for Vapor Pressure of Petroleum Products (Mini-Method—Atmospheric), approved June 1, 2013.
(18) ASTM D6378-10, Standard Test Method for Determination of Vapor Pressure (VPx) of Petroleum Products, Hydrocarbons, and Hydrocarbon Oxygenate Mixtures (Triple Expansion Method), approved October 1, 2010.
(19) ASTM D86-05, Standard Test Method for Distillation of Petroleum Products at Atmospheric Pressure, approved July 1, 2005.
(20) ASTM D5599-00(2010), Standard Test Method for Determination of Oxygenates in Gasoline by Gas Chromatography and Oxygen Selective Flame Ionization Detection, approved October 1, 2010.
(21) ASTM D4815-15a, Standard Test Method for Determination for MTBE, ETBE, TAME, DIPE, tertiary-Amyl Alcohol and C1 to C4 Alcohols in Gasoline by Gas Chromatography, approved April 21, 2015.
(b)
The revisions and addition read as follows:
(d) * * *
(1) The refiner or importer shall calculate the sulfur content of the batch by volume weighting the sulfur content of the gasoline or BOB and the sulfur content of the added oxygenate pursuant to one of the methods listed in paragraphs (d)(1)(i) and (ii) of this section. A refiner or importer must choose to use only one method during each annual compliance period.
(i) Testing the sulfur content of a sample of the oxygenate pursuant to § 80.46 or § 80.47, as applicable. The refiner or importer must demonstrate through records relating to sampling, testing, and blending that the test result was derived from a representative sample of the oxygenate that was blended with the batch of gasoline or BOB.
(ii) If the oxygenate is denatured fuel ethanol, and the sulfur content has not been tested under paragraph (d)(1)(i) of this section, then the sulfur content must be assumed to be 5.00 ppm.
(2) For denatured fuel ethanol, the refiner or importer may assume that the denatured fuel ethanol was blended with gasoline or BOB at a concentration of 10 volume percent, unless the refiner or importer can demonstrate that a different amount of denatured fuel ethanol was actually blended with a batch of gasoline or BOB.
(i) The refiner or importer of conventional gasoline or CBOB must comply with the requirements of § 80.101(d)(4)(ii).
(ii) The refiner or importer of reformulated gasoline or RBOB must comply with the requirements of § 80.69(a).
(ii) Any gasoline or BOB must meet the per-gallon sulfur standard of paragraph (a)(2) of this section prior to calculating any dilution from the oxygenate added downstream.
(iv) The reported volume of the batch is the combined volume of the reformulated gasoline, RBOB, conventional gasoline, or CBOB and the downstream added oxygenate.
(f) * * *
(1) * * *
OC = Sulfur credits used by the refinery or importer to show compliance, in ppm-gallons.
Beginning February 1, 2018, a refiner that produces E15 at a blender pump-refinery, as defined in § 80.1500, shall be deemed in compliance with the provisions of this subpart, provided the refiner is in compliance with the requirements for gasoline produced by blender pump-refiners in § 80.1530.
(a) * * * Such oxygenate blenders are subject to the requirements of paragraph (b) of this section, the requirements and prohibitions applicable to downstream parties, the requirements of § 80.1603(d)(3), and the prohibition specified in § 80.1660(e).
(c) * * *
(3) CR
(g) Small refiner and small volume refinery status applications, and any other correspondence required by this section, § 80.1620, or § 80.1621 shall be sent to the attention of “Tier 3 Program (Small Refiner/Small Volume Refinery Application)” to the address in § 80.10(a).
(c) * * *
(2) Hardship applications under this section must be sent to the attention of “Tier 3 Program (Hardship Application)” to the address in § 80.10(a).
(b) * * *
(3) Any oxygenate blender required to register shall do so by November 1, 2016, or at least 90 days in advance of the first date that such person will blend oxygenate into gasoline, RBOB, or CBOB where the resulting gasoline is subject to the gasoline sulfur standards under this subpart O.
(e) * * *
(1) * * *
(iii) * * *
(A) Whether records are kept on-site or off-site of the facility.
(g) * * *
(1) * * *
(iii) * * *
(A) Whether records are kept on-site or off-site of the facility.
(a) * * *
(7) For each batch of BOB or gasoline produced or imported during the averaging period, all the following:
(v) The type and amount of oxygenate, along with identification of the method used to determine the type and amount of oxygenate content of the batch, as determined under § 80.1603(d).
(vi) The sulfur content of the oxygenate, reported to two decimal places, along with identification of the method used to determine the sulfur content of the oxygenate, as determined under § 80.1603(d).
(h)
Category | Regulatory Information | |
Collection | Federal Register | |
sudoc Class | AE 2.7: GS 4.107: AE 2.106: | |
Publisher | Office of the Federal Register, National Archives and Records Administration |