Page Range | 44449-44813 | |
FR Document |
Page and Subject | |
---|---|
83 FR 44680 - Integrated Storage Partner's Waste Control Specialists Consolidated Interim Storage Facility | |
83 FR 44681 - Sunshine Act Meetings | |
83 FR 44675 - Sunshine Act Meetings | |
83 FR 44449 - Adjustment to Premium Processing Fee | |
83 FR 44670 - Environmental Impact Statement on the Liberty Development and Production Plan in the Beaufort Sea Planning Area | |
83 FR 44566 - Cast Iron Soil Pipe Fittings From the People's Republic of China: Countervailing Duty Order | |
83 FR 44570 - Cast Iron Soil Pipe Fittings From the People's Republic of China: Amended Final Determination of Sales at Less Than Fair Value and Antidumping Duty Order | |
83 FR 44644 - Fair Market Rents for the Housing Choice Voucher Program, Moderate Rehabilitation Single Room Occupancy Program, and Other Programs Fiscal Year 2019 | |
83 FR 44564 - Sunshine Act Meetings | |
83 FR 44688 - Clackamas Valley Railway, LLC-Lease and Operation Exemption With Interchange Commitment-Union Pacific Railroad Company | |
83 FR 44607 - Agency Information Collection Activities: Submission for OMB Review; Comment Request | |
83 FR 44673 - Agency Information Collection Activities; Comment Request; Information Collections: Work Study Program of the Child Labor Regulations | |
83 FR 44689 - Progressive Rail Incorporated-Continuance in Control Exemption-Clackamas Valley Railway, LLC | |
83 FR 44637 - Findings of Research Misconduct | |
83 FR 44528 - Clean Air Plans; 2008 8-Hour Ozone Nonattainment Area Requirements; San Joaquin Valley, California | |
83 FR 44623 - Public Listening Session; Stakeholder Input on Peak Flows Management | |
83 FR 44626 - Pesticide Product Registration; Receipt of Applications for New Active Ingredients | |
83 FR 44630 - Proposed Data Collection Submitted for Public Comment and Recommendations | |
83 FR 44631 - Agency Forms Undergoing Paperwork Reduction Act Review | |
83 FR 44628 - Agency Forms Undergoing Paperwork Reduction Act Review | |
83 FR 44669 - Market Centers for Use in Applying Royalty Valuation Regulations for Federal Oil | |
83 FR 44578 - Takes of Marine Mammals Incidental to Specified Activities; Taking Marine Mammals Incidental to a Marine Geophysical Survey in the North Pacific Ocean | |
83 FR 44605 - Procurement List; Additions and Deletions | |
83 FR 44604 - Procurement List; Proposed Addition and Deletions | |
83 FR 44607 - Procurement List; Additions; Corrections | |
83 FR 44681 - Proposed Submission of Information Collection for OMB Review; Comment Request; Qualified Domestic Relations Orders Submitted to PBGC | |
83 FR 44651 - 30-Day Notice of Proposed Information Collection: Local Appeals to Single-Family Mortgage Limits | |
83 FR 44651 - 30-Day Notice of Proposed Information Collection: Survey To Assess Operational and Capacity Status of Housing Counseling Agencies After a Disaster | |
83 FR 44659 - Notice of Error in Draft Resource Management Plans and Associated Environmental Impact Statement for the Grand Staircase-Escalante National Monument-Grand Staircase, Kaiparowits, and Escalante Canyon Units and Federal Lands Previously Included in the Monument That Are Excluded From the Boundaries; Extension of Public Comment Period, Utah | |
83 FR 44654 - Public Land Order No. 7873; Withdrawal of Public Land for Land Management Evaluation Purposes; Nevada | |
83 FR 44627 - Formations of, Acquisitions by, and Mergers of Bank Holding Companies | |
83 FR 44628 - Change in Bank Control Notices; Acquisitions of Shares of a Bank or Bank Holding Company | |
83 FR 44610 - Agency Information Collection Activities; Submission to the Office of Management and Budget for Review and Approval; Comment Request; Application for the Educational Flexibility (Ed-Flex) Program | |
83 FR 44654 - Notice of Filing of Plats of Survey, Colorado | |
83 FR 44652 - Draft Environmental Impact Statement and Draft Habitat Conservation Plan; Receipt of an Application for an Incidental Take Permit for Midwestern Bat and Bird Species; MidAmerican Energy Company, Iowa | |
83 FR 44474 - Schedules of Controlled Substances: Temporary Placement of N | |
83 FR 44687 - Privacy Act of 1974; Matching Program | |
83 FR 44672 - Bulk Manufacturer of Controlled Substances Application: National Center for Natural Products Research NIDA MPROJECT | |
83 FR 44609 - Notice of Availability of the Final Missouri River Recovery Management Plan and Environmental Impact Statement | |
83 FR 44674 - Agency Information Collection Activities: Comment Request | |
83 FR 44576 - North Pacific Fishery Management Council; Public Meeting | |
83 FR 44576 - South Atlantic Fishery Management Council; Public Meeting | |
83 FR 44575 - South Atlantic Fishery Management Council; Public Meetings | |
83 FR 44604 - North Pacific Fishery Management Council; Public Meeting | |
83 FR 44575 - New England Fishery Management Council; Public Meeting | |
83 FR 44603 - New England Fishery Management Council; Public Meeting | |
83 FR 44573 - Certain Steel Wheels From the People's Republic of China: Preliminary Affirmative Countervailing Duty Determination and Alignment of Final Determination With Final Antidumping Duty Determination | |
83 FR 44636 - Agency Information Collection Request. 30-Day Public Comment Request | |
83 FR 44635 - Agency Information Collection Request; 30-Day Public Comment Request | |
83 FR 44634 - Agency Information Collection Request; 30-Day Public Comment Request | |
83 FR 44565 - Membership of the Departmental Performance Review Board | |
83 FR 44567 - Cast Iron Soil Pipe From the People's Republic of China: Preliminary Affirmative Determination of Sales at Less Than Fair Value and Postponement of Final Determination | |
83 FR 44565 - Foreign-Trade Zone 259-Koochiching County, Minnesota; Application for Subzone; Digi-Key Corporation; Thief River Falls, Minnesota | |
83 FR 44637 - Agency Information Collection Request. 30-Day Public Comment Request | |
83 FR 44638 - Agency Information Collection Request. 30-Day Public Comment Request | |
83 FR 44635 - Agency Information Collection Request. 30-Day Public Comment Request | |
83 FR 44562 - Concurrence With OIE Risk Designations for Bovine Spongiform Encephalopathy | |
83 FR 44632 - Medicare & Medicaid Programs, and Other Program Initiatives, and Priorities; Meeting of the Advisory Panel on Outreach and Education (APOE), September 26, 2018 | |
83 FR 44482 - Outdated or Superseded Regulations: Title I, Parts A Through C; Christa McAuliffe Fellowship Program; and Empowerment Zone or Enterprise Community-Priority; Correction | |
83 FR 44563 - Notice of Intent To Seek Approval To Revise and Extend a Currently Approved Information Collection | |
83 FR 44562 - Notice of Intent To Request Revision and Extension of a Currently Approved Information Collection | |
83 FR 44613 - Panhandle Eastern Pipe Line Company, LP; Notice of Request Under Blanket Authorization | |
83 FR 44612 - Combined Notice of Filings #1 | |
83 FR 44611 - Methane Hydrate Advisory Committee | |
83 FR 44622 - Information Collection Request Submitted to OMB for Review and Approval; Comment Request; Producers, Registrants and Applicants of Pesticides and Pesticide Devices Under Section 8 of the Federal Insecticide, Fungicide, and Rodenticide Act (Renewal) | |
83 FR 44621 - Information Collection Request Submitted to OMB for Review and Approval; Comment Request; Aircraft Engines-Supplemental Information Related to Exhaust Emissions (Renewal) | |
83 FR 44627 - Information Collection Request Submitted to OMB for Review and Approval; Comment Request; Cross-State Air Pollution Rule and Texas SO2 | |
83 FR 44622 - Information Collection Request Submitted to OMB for Review and Approval; Comment Request; NSPS for Sulfuric Acid Plants (Renewal) | |
83 FR 44693 - Agency Information Collection: Activity for OMB Review: Agency Request for Reinstatement of a Previously Approved Information Collection: 2105-0009, Advisory Committee Candidate Biographical Information Request Form | |
83 FR 44615 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization; Enel Green Power Diamond Vista Wind Project, LLC | |
83 FR 44618 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization: SF Wind Enterprises, LLC | |
83 FR 44612 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization: Rose Wind Holdings, LLC | |
83 FR 44621 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization; Rose Creek Wind, LLC | |
83 FR 44615 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization; K&K Wind Enterprises, LLC | |
83 FR 44614 - Garwind, LLC; Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization | |
83 FR 44615 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization; Bobilli BSS, LLC | |
83 FR 44617 - Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization; Adams Wind Farm, LLC | |
83 FR 44617 - Combined Notice of Filings #2 | |
83 FR 44616 - Combined Notice of Filings #1 | |
83 FR 44566 - Transportation and Related Equipment Technical Advisory Committee; Notice of Partially Closed Meeting | |
83 FR 44661 - National Register of Historic Places; Notification of Pending Nominations and Related Actions | |
83 FR 44480 - Safety Zone; Fireworks Display, Indian River Bay, Long Neck, DE | |
83 FR 44611 - Environmental Management Site-Specific Advisory Board, Hanford | |
83 FR 44548 - Fisheries of the Northeastern United States; Atlantic Mackerel, Squid, and Butterfish; Amendment 20 | |
83 FR 44675 - Meeting of the Advisory Committee on Reactor Safeguards | |
83 FR 44625 - Environmental Impact Statements; Notice of Availability | |
83 FR 44482 - Safety Zone; Annual Swim for Alligator Reef Lighthouse, Islamorada, FL | |
83 FR 44479 - Drawbridge Operation Regulation; New Jersey Intracoastal Waterway (NJICW), Atlantic City, NJ | |
83 FR 44478 - Drawbridge Operation Regulation; Trent River, New Bern, NC | |
83 FR 44662 - Agency Information Collection Activities: Royalty and Production Reporting | |
83 FR 44676 - First Energy Corp.; First Energy Solutions; FirstEnergy Nuclear Generation; FirstEnergy Nuclear Operating Company | |
83 FR 44677 - Exelon Generation Company, LLC; Byron Station, Unit Nos. 1 and 2 | |
83 FR 44564 - Publication of Depreciation Rates | |
83 FR 44641 - Accreditation and Approval of Inspectorate America Corporation (Pasadena, TX), as a Commercial Gauger and Laboratory | |
83 FR 44691 - Notice of Final Federal Agency Actions on the Wainiha Bridges Along State Route 560 in the State of Hawaii | |
83 FR 44696 - Agency Information Collection Activity Under OMB Review: Application for Reimbursement of Licensing or Certification Test Fees | |
83 FR 44696 - Agency Information Collection Activity: Payment or Reimbursement for Emergency Services for Nonservice-Connected Conditions in Non-Department Facilities | |
83 FR 44617 - Texas Eastern Transmission, LP; Notice of Request Under Blanket Authorization | |
83 FR 44618 - D'Lo Gas Storage, LLC; Notice of Intent to Prepare an Environmental Assessment for the Proposed D'Lo Natural Gas Storage Project Amendment, and Request for Comments on Environmental Issues | |
83 FR 44694 - Agency Information Collection Activity Under OMB Review: Advertising, Sales, and Enrollment Materials, and Candidate Handbook | |
83 FR 44694 - Agency Information Collection Activity Under OMB Review: Appointment of Veterans Service Organization as Claimant's Representative and Appointment of Individual as Claimant's Representative | |
83 FR 44695 - Agency Information Collection Activity Under OMB Review: The Veterans' Outcome Assessment (VOA) (Veteran Survey Interview) | |
83 FR 44671 - Agency Information Collection Activities; Lower Colorado River Well Inventory | |
83 FR 44639 - National Institute of General Medical Sciences; Notice of Closed Meeting | |
83 FR 44639 - National Institute on Alcohol Abuse and Alcoholism; Notice of Closed Meetings | |
83 FR 44638 - National Institute of General Medical Sciences; Notice of Closed Meeting | |
83 FR 44641 - National Institute on Aging; Notice of Closed Meeting | |
83 FR 44640 - National Institute on Aging; Notice of Closed Meeting | |
83 FR 44640 - Center for Scientific Review; Notice of Closed Meetings | |
83 FR 44639 - Center for Scientific Review; Notice of Closed Meetings | |
83 FR 44686 - Self-Regulatory Organizations; Cboe BZX Exchange, Inc.; Notice of Filing and Immediate Effectiveness of a Proposed Rule Change To Delete Obsolete Language Regarding the Timing of Listing Long-Term Options Series | |
83 FR 44684 - Self-Regulatory Organizations; Cboe EDGX Exchange, Inc.; Notice of Filing and Immediate Effectiveness of a Proposed Rule Change To Delete Obsolete Language Regarding the Timing of Listing Long-Term Options Series | |
83 FR 44682 - Self-Regulatory Organizations; BOX Exchange LLC; Notice of Filing and Immediate Effectiveness of a Proposed Rule Change To Amend BOX Rules 5050 and 5070 | |
83 FR 44500 - Interstate Transport Prongs 1 and 2 for the 2010 Sulfur Dioxide (SO2 | |
83 FR 44608 - Defense Advisory Committee on Investigation, Prosecution, and Defense of Sexual Assault in the Armed Forces; Notice of Federal Advisory Committee Meeting | |
83 FR 44467 - Floating Cabin Regulation | |
83 FR 44671 - Certain Dental Ceramics, Products Thereof, and Methods of Making the Samel; Notice of Request for Statements on the Public Interest | |
83 FR 44455 - Special Conditions: Ultramagic S.A., Model M-56, M-56C, M-65, M-65C, M-77, M-77C, M-90, M-105, M-120, M-130, M-145, M-160, N-180, N-210, N-250, N-300, N-355, N-425, S-70, S-90, S-105, S-130, S-160, T-150, T-180, T-210, V-56, V-65, V-77, V-90, and V-105 Balloons; Balloon Passenger Basket, Model CV-08, Seat Installation | |
83 FR 44689 - Agency Information Collection Activities: Requests for Comments; Clearance of Renewed Approval of Information Collection: Operating Requirements: Commuter and On-Demand Operation | |
83 FR 44690 - Agency Information Collection Activities: Requests for Comments; Clearance of Renewed Approval of Information Collection: Certification: Pilots and Flight Instructors | |
83 FR 44642 - Agency Information Collection Activities: Designation of Attorney in Fact; Extension, Without Change, of Currently Approved Collection | |
83 FR 44643 - Agency Information Collection Activities; Extension, Without Change, of a Currently Approved Collection: Application for Relief Under Former Section 212(c) of the Immigration and Nationality Act | |
83 FR 44643 - Agency Information Collection Activities; Extension, Without Change, of a Currently Approved Collection: Refugee/Asylee Relative Petition | |
83 FR 44479 - Drawbridge Operation Regulation; Charenton Canal, Baldwin, LA | |
83 FR 44673 - Corrected Notice of Lodging Proposed Consent Decree | |
83 FR 44688 - United States Passports Invalid for Travel to, in, or Through the Democratic People's Republic of Korea | |
83 FR 44498 - Air Plan Approval; District of Columbia; State Implementation Plan for the Interstate Transport Requirements for the 2008 Ozone Standard | |
83 FR 44482 - Approval and Promulgation of Air Quality Implementation Plans; Maryland; Infrastructure Requirements for the 2012 Fine Particulate Matter National Ambient Air Quality Standard | |
83 FR 44485 - Air Plan Approval; Michigan; Minor New Source Review | |
83 FR 44510 - Airworthiness Directives; Airbus SAS Airplanes | |
83 FR 44516 - Airworthiness Directives; Airbus SAS Airplanes | |
83 FR 44508 - Airworthiness Directives; The Boeing Company Airplanes | |
83 FR 44514 - Airworthiness Directives; Airbus SAS Airplanes | |
83 FR 44746 - Emission Guidelines for Greenhouse Gas Emissions From Existing Electric Utility Generating Units; Revisions to Emission Guideline Implementing Regulations; Revisions to New Source Review Program | |
83 FR 44460 - Airworthiness Directives; Airbus SAS Airplanes | |
83 FR 44463 - Airworthiness Directives; ATR-GIE Avions de Transport Régional Airplanes | |
83 FR 44457 - Airworthiness Directives; Airbus SAS Airplanes | |
83 FR 44660 - Notice of Availability for the Draft Environmental Impact Statement for the Proposed Ten West Link 500-Kilovolt Transmission Line Project and Draft Amendments to the Yuma Field Office Resource Management Plan and the California Desert Conservation Area Plan; Maricopa and La Paz Counties, Arizona, and Riverside County, California | |
83 FR 44504 - Single Family Housing Direct and Guaranteed Loan Programs | |
83 FR 44451 - Liquidity Coverage Ratio Rule: Treatment of Certain Municipal Obligations as High-Quality Liquid Assets | |
83 FR 44465 - Delegation of Authority to General Counsel of the Commission | |
83 FR 44521 - Standards for Business Practices of Interstate Natural Gas Pipelines | |
83 FR 44700 - Amendments to Municipal Securities Disclosure | |
83 FR 44692 - Proposed Agency Information Collection Activities; Comment Request |
Animal and Plant Health Inspection Service
National Agricultural Statistics Service
Rural Housing Service
Rural Utilities Service
Foreign-Trade Zones Board
Industry and Security Bureau
International Trade Administration
National Oceanic and Atmospheric Administration
Engineers Corps
Federal Energy Regulatory Commission
Centers for Disease Control and Prevention
Centers for Medicare & Medicaid Services
National Institutes of Health
Coast Guard
U.S. Citizenship and Immigration Services
U.S. Customs and Border Protection
U.S. Immigration and Customs Enforcement
Fish and Wildlife Service
Land Management Bureau
National Park Service
Ocean Energy Management Bureau
Office of Natural Resources Revenue
Reclamation Bureau
Drug Enforcement Administration
Wage and Hour Division
Federal Aviation Administration
Federal Highway Administration
Federal Railroad Administration
Comptroller of the Currency
Consult the Reader Aids section at the end of this issue for phone numbers, online resources, finding aids, and notice of recently enacted public laws.
To subscribe to the Federal Register Table of Contents electronic mailing list, go to https://public.govdelivery.com/accounts/USGPOOFR/subscriber/new, enter your e-mail address, then follow the instructions to join, leave, or manage your subscription.
U.S. Citizenship and Immigration Services, DHS.
Final rule.
The Department of Homeland Security (DHS) is increasing the premium processing fee charged by U.S. Citizenship and Immigration Services (USCIS). DHS is increasing the fee by 14.92 percent, the percentage change in inflation since the fee was last adjusted in 2010 according to the Consumer Price Index for All Urban Consumers (CPI-U). The adjustment increases the fee from $1,225 to $1,410.
This rule is effective on October 1, 2018. Applications postmarked on or after that date must include the new fee.
Joseph D. Moore, Chief Financial Officer, U.S. Citizenship and Immigration Services, U.S. Department of Homeland Security, 20 Massachusetts Avenue NW, Washington, DC 20529-2130; or by phone at (202) 272-1969 (this is not a toll-free number).
The Immigration and Nationality Act (INA) permits certain employment-based immigration benefit applicants and petitioners to request, for a fee, premium processing. The applicable statute authorizes the Secretary of Homeland Security (Secretary) to charge and collect a premium processing fee for employment-based petitions and applications. The fee must be used to provide certain premium-processing services to business customers, and to make infrastructure improvements in the adjudications and customer service processes. By statute, the fee, initially set at $1,000, must be paid in addition to any normal petition/application fee that may be applicable. The statute provides that the Secretary may adjust this fee according to the Consumer Price Index. INA section 286(u), 8 U.S.C. 1356(u); Public Law 106-553, App. B, tit. I, sec. 112, 114 Stat. 2762, 2762A-68 (Dec. 21, 2000).
Premium processing allows filers to request 15-day processing of certain employment-based immigration benefit requests if they pay an extra amount.
Premium processing is currently authorized for certain petitioners filing a Petition for a Nonimmigrant Worker (Form I-129), or an Immigrant Petition for Alien Worker (Form I-140) seeking certain employment-based classifications.
Consistent with INA section 286(u), 8 U.S.C. 1356(u), DHS has calculated the percent change in the CPI-U to measure inflation. For the end point for the period of inflation to establish the current premium processing fee, DHS used the Consumer Price Index-Urban Consumers (CPI-U) as of June 2010.
USCIS intends to use the premium funds that are generated by the fee increase to provide certain premium-processing services to business customers, and to make infrastructure improvements in the adjudications and customer-service processes. In recent years, premium processing has been suspended on employment-based petitions to permit officers working on premium processing cases to process long-pending non-premium filed petitions as well as to prevent a lapse in employment authorization for beneficiaries of extension petitions resulting from the high volume of incoming petitions and a significant surge in premium processing requests.
A request for premium processing postmarked on or after October 1, 2018 must include the new fee. Petitioners must pay the $1,410 fee in addition to and separate from other filing fees. 8 CFR 103.7(b)(1)(i)(SS)(
DHS is making this fee increase final without notice and comment because it is unnecessary. 5 U.S.C. 553(b)(B). By law, DHS may adjust the premium processing fee for inflation according to the Consumer Price Index.
Because this action is not subject to the notice-and-comment requirements under the APA, a final regulatory flexibility analysis is not required.
Finally, this action does not require review by the Office of Management and Budget (OMB) under Executive Orders 12866 and 13563. As previously discussed, DHS has the authority to adjust the premium processing fees according to the CPI-U. DHS is adjusting the premium processing fee by 14.92 percent resulting in an increase of $185 per Form I-907 (from a fee of $1,225 per premium processing Form I-907 to $1,410 per Form I-907). Table 1 shows the total number of premium processing Forms I-907 received by USCIS from fiscal year 2013 to 2017. On average, USCIS received 238,784 Forms I-907 annually during this timeframe.
DHS estimates an additional annual $44 million in revenue to be collected from the increase in premium processing fees due to adjustment of inflation.
This rule imposes transfer payments between the public and the government. Thus, this action is exempt from Executive Order 13771.
Administrative practice and procedure, Authority delegations (Government agencies), Freedom of information, Immigration, Privacy, Reporting and recordkeeping requirements, Surety bonds.
For the reasons stated in the preamble, DHS amends part 103 of chapter I of title 8 of the Code of Federal Regulations as follows:
5 U.S.C. 301, 552, 552a; 8 U.S.C. 1101, 1103, 1304, 1356; 31 U.S.C. 9701; 48 U.S.C. 1806; Pub. L. 107-296, 116 Stat. 2135 (6 U.S.C. 1
Office of the Comptroller of the Currency (OCC), Treasury; Board of Governors of the Federal Reserve System (Board); and Federal Deposit Insurance Corporation (FDIC).
Interim final rule with request for comment.
The OCC, the Board, and the FDIC (collectively, the agencies) are jointly issuing and inviting comment on an interim final rule that amends the agencies' liquidity coverage ratio (LCR) rule to treat liquid and readily-marketable, investment grade municipal obligations as high-quality liquid assets (HQLA). Section 403 of the Economic Growth, Regulatory Relief, and Consumer Protection Act amends section 18 of the Federal Deposit Insurance Act and requires the agencies, for purposes of their LCR rule and any other regulation that incorporates a definition of the term “high-quality liquid asset” or another substantially similar term, to treat a municipal obligation as HQLA (that is a level 2B liquid asset) if that obligation is, as of the LCR calculation date, “liquid and readily-marketable” and “investment grade.”
The interim final rule is effective on August 31, 2018. Comments on the interim final rule must be received by October 1, 2018.
Comments should be directed to:
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You may review comments and other related materials that pertain to this rulemaking action by any of the following methods:
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The Office of the Comptroller of the Currency (OCC), the Board of Governors of the Federal Reserve System (Board), and the Federal Deposit Insurance Corporation (FDIC) (collectively, the agencies) adopted the liquidity coverage ratio (LCR) rule
In 2016, the Board amended its LCR rule to include certain U.S. municipal securities as HQLA, subject to certain limitations (2016 Amendments).
The Economic Growth, Regulatory Relief, and Consumer Protection Act (EGRRCPA) was enacted on May 24, 2018.
This interim final rule amends the agencies' LCR rule to implement section 403 of the EGRRCPA. Section 403 requires the agencies to treat a municipal obligation as a level 2B liquid asset if the obligation, as of the calculation date, is liquid and readily-marketable and investment grade.
The interim final rule adds a definition to the agencies' rule for the term “municipal obligations,” which, consistent with the EGRRCPA, means an obligation of (1) a state or any political subdivision thereof or (2) any agency or instrumentality of a state or any political subdivision thereof.
The interim final rule amends the HQLA criteria with respect to level 2B liquid assets by adding municipal obligations that, as of the calculation date, are both (1) liquid and readily-marketable and (2) investment grade (under 12 CFR part 1) to the list of assets that are eligible for treatment as level 2B liquid assets.
Consistent with section 403, the interim final rule also amends the definition of “liquid and readily-marketable” in the FDIC's and OCC's rules so that the term has the same meaning given to it under the Board's rules. Under this provision of the Board's rules, a “liquid and readily-marketable” security is a security that is traded in an active secondary market with: (1) More than two committed market makers; (2) a large number of non-market maker participants on both the buying and selling sides of transactions; (3) timely and observable market prices; and (4) a high trading volume.
As part of the interim final rule, the Board is rescinding the 2016 Amendments so that municipal obligations under the Board's LCR rule will be treated consistently with section 403 of the EGRRCPA. As a result of the above changes, covered companies will be able to count municipal obligations as HQLA that qualify as level 2B liquid assets, provided the municipal obligations meet the HQLA criteria under the LCR rule.
Only municipal obligations that meet the LCR rule's definition for liquid and readily-marketable and that are investment grade under 12 CFR part 1 will qualify for treatment as HQLA under this interim final rule.
The definition of “municipal obligation” and the criteria for treating municipal obligations as level 2B liquid assets were established by section 403 of the EGRRCPA. Consistent with section 403, in what ways, if any, could the agencies clarify aspects of these provisions (
The agencies are issuing the interim final rule without prior notice and the opportunity for public comment and the 30 day delayed effective date ordinarily prescribed by the Administrative Procedure Act (APA).
As discussed above, this interim final rule implements the provisions of section 403 of the EGRRCPA, which became effective on May 24, 2018, and directs the agencies to make certain changes to the criteria for HQLA. The interim final rule adopts without change the statutory definition for “municipal obligations” and the requirement that municipal obligations be treated as level 2B liquid assets if the obligations are liquid and readily-marketable and investment grade. Because these changes to the LCR rule are mandated by the EGRRCPA, the agencies have determined that publishing a notice of proposed rulemaking is unnecessary. In addition, the agencies believe that the public interest is best served by implementing Congress's legislative directive as soon as possible because immediate implementation would provide clarity to the public regarding the liquidity rules and would be consistent with Congress's directive to the agencies under section 403(b) of the EGRRCPA to amend the LCR rule within 90 days after enactment of the EGRRCPA.
The effective date of this interim final rule is August 31, 2018. Pursuant to section 553(d)(3) of the APA, the required publication or service of a substantive rule shall be made not less than 30 days before its effective date, except as otherwise provided by the agency for good cause found and published with the rule.
Pursuant to section 302(a) of the Riegle Community Development and Regulatory Improvement Act (RCDRIA),
While the agencies believe there is good cause to issue the rules without advance notice and comment and with an immediate effective date, the agencies are interested in the views of the public and request comment on all aspects of the interim final rule.
The Regulatory Flexibility Act (RFA) does not apply to a rulemaking when a general notice of proposed rulemaking is not required. 5 U.S.C. 603 and 604. As noted previously, the agencies have determined that it is unnecessary to publish a general notice of proposed rulemaking for this interim final rule. Accordingly, the RFA's requirements relating to an initial and final regulatory flexibility analysis do not apply. Nonetheless, the agencies observe that in light of the way the interim final rule operates, they believe that, with respect to the entities subject to the interim final rule and within each agency's respective jurisdiction, the interim final rule would not have a significant economic impact on a substantial number of small entities.
The Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3521) states that no agency may conduct or sponsor, nor is the respondent required to respond to, an information collection unless it displays a currently valid Office of Management and Budget control number. The agencies have determined that this interim final rule does not create any new, or revise any existing, collections of information pursuant to the Paperwork Reduction Act.
Section 202 of the Unfunded Mandates Reform Act of 1995 (Unfunded Mandates Act), 2 U.S.C. 1532, requires the OCC to prepare a budgetary impact statement before promulgating any final rule for which a general notice of proposed rulemaking was published. As discussed above, the OCC has determined that the publication of a general notice of proposed rulemaking is unnecessary. Accordingly, this interim final rule is not subject to section 202 of the Unfunded Mandates Act.
Administrative practice and procedure, Banks, Banking, Liquidity, Reporting and recordkeeping requirements, Savings associations.
Administrative practice and procedure, Banks, Banking, Federal Reserve System, Holding companies, Liquidity, Reporting and recordkeeping requirements.
Administrative practice and procedure, Banks, Banking, Federal Deposit Insurance Corporation, FDIC, Liquidity, Reporting and recordkeeping requirements.
For the reasons stated in the preamble, the OCC amends 12 CFR part 50, the Board amends 12 CFR part 249, and the FDIC amends 12 CFR part 329 as follows:
12 U.S.C. 1
(1) A state or any political subdivision thereof; or
(2) Any agency or instrumentality of a state or any political subdivision thereof.
The republication and addition read as follows:
(c)
(3) A municipal obligation that is investment grade under 12 CFR part 1 as of the calculation date.
12 U.S.C. 248(a), 321-338a, 481-486, 1467a(g)(1), 1818, 1828, 1831p-1, 1831o-1, 1844(b), 5365, 5366, 5368.
(1) A state or any political subdivision thereof; or
(2) Any agency or instrumentality of a state or any political subdivision thereof.
(c)
(3) A municipal obligation that is investment grade under 12 CFR part 1 as of the calculation date.
12 U.S.C. 1815, 1816, 1818, 1819, 1828, 1831p-1, 5412.
(1) A state or any political subdivision thereof; or
(2) Any agency or instrumentality of a state or any political subdivision thereof.
The republication and addition read as follows:
(c)
(3) A municipal obligation that is investment grade under 12 CFR part 1 as of the calculation date.
By order of the Board of Directors.
Federal Aviation Administration (FAA), DOT.
Final special conditions.
These special conditions are issued for Ultramagic S.A. Models M-56, M-56C, M-65, M-65C, M-77, M-77C, M-90, M-105, M-120, M-130, M-145, M-160, N-180, N-210, N-250, N-300, N-355, N-425, S-70, S-90, S-105, S-130, S-160, T-150, T-180, T-210, V-56, V-65, V-77, V-90, and V-105 balloons. These balloons will have novel or unusual design features associated with a standard construction basket with a singular distribution that includes four occupant seats and a lower sidewall. The applicable airworthiness regulations do not contain adequate or appropriate safety standards for these design features. These special conditions contain the additional safety standards the Administrator considers necessary to establish a level of safety equivalent to that established by the existing airworthiness standards.
These special conditions are effective August 31, 2018.
Robert Stegeman, FAA, AIR-691, Policy & Innovation Division, Small Airplane Standards Branch, Aircraft Certification Service, 901 Locust, Kansas City, Missouri 64106; telephone (816) 329-4140; facsimile (816) 329-4090.
On August 4, 2016, Ultramagic S.A. (Ultramagic) applied for a change to Type Certificate (TC) No. B02CE
Most balloon baskets accommodate standing passengers. The CV-08 differs by incorporating passenger seats, restraints, and a lower basket sidewall. Due to the lower sidewall and seat configuration, passengers would need to remain seated and restrained with safety belts during flight. This configuration should consider the static strength of the installations, the possible loads in an accident, and the effect on passenger safety. Accident impact should consider safety comparison between a restrained, sitting occupant; and a normal, standing occupant. Safety requirements for balloon-seated occupants are not included in the existing airworthiness regulations. These special conditions evaluate the seat installations and restraints using methods consistent with special conditions issued by the European Aviation Safety Agency (EASA). The EASA special conditions are based upon a German standard for seats in hot air airships.
Under the provisions of § 21.101, Ultramagic must show that the M-56, M-56C, M-65, M-65C, M-77, M-77C, M-90, M-105, M-120, M-130, M-145, M-160, N-180, N-210, N-250, N-300, N-355, N-425, S-70, S-90, S-105, S-130, S-160, T-150, T-180, T-210, V-56, V-65, V-77, V-90, and V-105 balloon models—coupled with the CV-08 basket—continues to meet the applicable provisions of the regulations incorporated by reference in TC No. B02CE or the applicable regulations in effect on the date of application for the change. The regulations incorporated by reference in the type certificate are commonly referred to as the “original type certification basis.” The regulations incorporated by reference in TC No. B02CE are as follows:
14 CFR 21.29 and part 31, effective on January, 1990, as amended by 31-1 through 31-5 inclusive.
Equivalent level of Safety findings per provision of 14 CFR 21.21(b)(1):
Special Conditions 31-001-SC applicable to MK-32 model burners.
If the Administrator finds that the applicable airworthiness regulations (
Special conditions are initially applicable to the model(s) for which they are issued. Should the type certificate for that model be amended later to include any other model that incorporates the same or similar novel or unusual design feature, or should any other model already included on the same type certificate be modified to incorporate the same or similar novel or unusual design feature, the FAA would apply these special conditions to the other model under § 21.101.
The FAA issues special conditions, as defined in 14 CFR 11.19, in accordance with § 11.38, and they become part of the type-certification basis under § 21.101.
The M-56, M-56C, M-65, M-65C, M-77, M-77C, M-90, M-105, M-120, M-130, M-145, M-160, N-180, N-210, N-250, N-300, N-355, N-425, S-70, S-90, S-105, S-130, S-160, T-150, T-180, T-210, V-56, V-65, V-77, V-90, and V-105 balloon models coupled with a CV-08 basket will incorporate the following novel or unusual design features:
Occupant seats with restraints and a lowered basket side rail.
Neither the FAA's airworthiness standards (14 CFR part 31, amendment 31-5), nor EASA's current Certification Specification (CS) for Hot Air Balloons (CS 31HB, amendment 1), incorporate specific requirements for seat and seat belts.
EASA previously published a proposed special condition
Notice of proposed special conditions No. 31-18-01-SC for the Ultramagic Balloon Models M-56, M-56C, M-65, M-65C, M-77, M-77C, M-90, M-105, M-120, M-130, M-145, M-160, N-180, N-210, N-250, N-300, N-355, N-425, S-70, S-90, S-105, S-130, S-160, T-150, T-180, T-210, V-56, V-65, V-77, V-90, and V-105 was published in the
As discussed above, these special conditions are applicable to the Model M-56, M-56C, M-65, M-65C, M-77, M-77C, M-90, M-105, M-120, M-130, M-145, M-160, N-180, N-210, N-250, N-300, N-355, N-425, S-70, S-90, S-105, S-130, S-160, T-150, T-180, T-210, V-56, V-65, V-77, V-90, and V-105 balloons. Should Ultramagic apply at a later date for a change to the type certificate to include another model incorporating the same novel or unusual design feature, the FAA would apply these special conditions to that model as well.
This action affects only certain novel or unusual design features on the balloon models specified in these special conditions. It is not a rule of general applicability and it affects only the applicant who applied to the FAA for approval of these features on the airplane. These special conditions are identical in intent to the EASA special conditions, although the formatting has been altered to meet these special condition requirements.
Aircraft, Aviation safety.
The authority citation for these special conditions is as follows:
49 U.S.C. 106(g), 40113, 44701-44702, 44704.
For calculation purposes, it should be assumed the mass of an occupant is at least 86 kilograms (190 pounds).
For each seat, safety belt, and harness, its attachment to the structure must be shown, by analysis, tests, or both, to be able to withstand the inertia forces prescribed in paragraph (c) of these special conditions multiplied by a fitting factor of 1.33.
The balloon—although it may be damaged under emergency landing conditions—must be designed to give each occupant every reasonable chance of avoiding serious injury in a crash landing—when seat belts provided for in the design are properly used—and the occupant is subject to the following ultimate inertia forces acting relative to the surrounding structure as well as independently of each other.
(1) Each seat and its supporting structure must be designed for an occupant mass in accordance paragraph (a) of these special conditions and for the maximum load factors corresponding to the specified flight and ground load conditions, including the emergency landing conditions prescribed in paragraph (c) of these special conditions.
(2) Each seat or berth shall be fitted with an individual approved seat belt or harness.
(3) Seat belts installed on the balloon must not fail under flight or ground load conditions or emergency landing conditions in accordance with paragraph (c) of these special conditions, taking into account the geometrical arrangement of the belt attachment and the seat.
Federal Aviation Administration (FAA), Department of Transportation (DOT).
Final rule.
We are superseding Airworthiness Directive (AD) 2015-02-17, which applied to all Airbus Model A330-200, A330-200 Freighter, and A330-300 series airplanes. AD 2015-02-17 required revising the electrical emergency configuration procedure in the Emergency Procedures section of the airplane flight manual (AFM) to include procedures for deploying the ram air turbine manually to provide sufficient hydraulic power and avoid constant speed motor/generator (CSM/G) shedding. Since we issued AD 2015-02-17, we have determined that replacement or modification of the two flight warning computers (FWCs) is necessary to address the identified unsafe condition. This AD requires the replacement or modifications of the two FWCs. This AD also removes airplanes from the applicability. We are issuing this AD to address the unsafe condition on these products.
This AD is effective October 5, 2018.
The Director of the Federal Register approved the incorporation by reference of a certain publication listed in this AD as of October 5, 2018.
The Director of the Federal Register approved the incorporation by reference of certain other publications listed in this AD as of February 13, 2015 (80 FR 4762, January 29, 2015).
For service information identified in this final rule, contact Airbus SAS, Airworthiness Office—EAW, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
You may examine the AD docket on the internet at
Vladimir Ulyanov, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3229.
We issued a notice of proposed rulemaking (NPRM) to amend 14 CFR part 39 to supersede AD 2015-02-17,
The European Aviation Safety Agency (EASA), which is the Technical Agent for the Member States of the European Union, has issued EASA AD 2017-0105R1, dated July 17, 2017 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for all Airbus SAS Model A330-200, A330-200 Freighter, and A330-300 series airplanes. The MCAI states:
The Constant Speed Motor/Generator (CSM/G), as installed on Airbus A330 aeroplanes, is qualified for an overload condition of 9.5 kVA [kilovolt-ampere] for 30 minutes. This duration is sufficient to perform safe landing and go-around. However, electrical load analysis revealed that the hydraulic power might not be sufficient to supply the CSM/G during slat/flap extension, when only one engine is running.
This condition, if not corrected, and in conjunction with the loss of main system, could lead to a scenario where the crew is not clearly warned that the electrical system has switched on the battery and thus has a limited duration to support a safe landing.
To initially address this potential unsafe condition, Airbus issued an Aircraft Flight Manual (AFM) Temporary Revision (TR) to amend the electrical emergency configuration “ELEC EMER CONFIG” procedure to require the pilot to deploy the ram air turbine manually before setting the Landing Recovery to “ON” position, which provides sufficient hydraulic power and avoids CSM/G shedding under worst-case operational conditions. Consequently, EASA issued AD 2014-0273 to require amendment of the AFM by incorporating the applicable Airbus TR.
After finding that [EASA] AD 2014-0273 contained some incorrect and incomplete information, EASA issued AD 2014-0281 [which corresponds to FAA AD 2015-02-17], retaining the requirements of EASA AD 2014-0273, which was superseded, but correcting the information related to premod/pre Service Bulletin (SB) or post-mod/post SB aeroplane configurations.
Since EASA AD 2014-0281 was issued, in order to improve the “ELEC EMER CONFIG” procedure, Airbus developed modifications to install improved FWCs, which is embodied in production through Airbus modification (mod) 205228, and to be embodied in service with Airbus SB A330-31-3232 * * *.
For the reasons described above, this [EASA] AD retains the requirements of EASA AD 2014-0281, which is superseded, and requires installation of a software standard upgrade [or replacement] of the two FWCs and removal of the applicable AFM TR once the aeroplane is modified.
Since EASA AD 2017-0105 was issued, it was identified that there was no need to require removal of applicable AFM TR, nor incorporation of a later AFM revision, as the contents are identical. This revised [EASA] AD deletes the requirement of paragraph (3) [of EASA AD 2017-0105].
You may examine the MCAI in the AD docket on the internet at
We gave the public the opportunity to participate in developing this final rule. The following presents the comments received on the NPRM and the FAA's response to each comment. The Air Line Pilots Association, International (ALPA), indicated its support for the NPRM.
Delta Air Lines requested that paragraph (l) of the proposed AD, “Credit for Previous Actions,” include Airbus Service Bulletin A330-31-3232, Revision 01, dated February 14, 2017, as well as Airbus Service Bulletin A330-31-3232, dated May 4, 2016.
We disagree this change is necessary. Paragraph (f) of this AD requires compliance with this AD unless already done. Paragraph (j) of this AD mandates actions in accordance with Airbus Service Bulletin A330-31-3232, Revision 01, dated February 14, 2017. Therefore, as specified in paragraph (f) of this AD, having previously accomplished the actions specified in Airbus Service Bulletin A330-31-3232, Revision 01, dated February 14, 2017, means compliance with paragraph (j) of this AD has already been established. In paragraph (l) of this AD, we give credit to operators that have previously accomplished an earlier revision of the required service information identified in paragraph (j) of this AD; therefore, as specified in paragraph (l) of this AD, having accomplished Airbus Service Bulletin A330-31-3232, dated May 4, 2016, prior to the effective date of this AD means compliance with paragraph (j) of this AD has already been established. We have not changed this AD in this regard.
We reviewed the relevant data, considered the comments received, and determined that air safety and the public interest require adopting this final rule as proposed, except for minor editorial changes. We have determined that these minor changes:
• Are consistent with the intent that was proposed in the NPRM for addressing the unsafe condition; and
• Do not add any additional burden upon the public than was already proposed in the NPRM.
Airbus SAS has issued A330/A340 Airplane Flight Manual (AFM) Temporary Revision (TR) TR427, UPDATE OF ELEC—EMER CONFIG PROCEDURE, Issue 1.0, dated November 7, 2014; and A330/A340 AFM TR TR428, UPDATE OF ELEC—EMER CONFIG PROCEDURE, Issue 1.0, dated November 7, 2014. This service information describes updated electrical emergency configuration procedures in the AFM. This service information is distinct because it applies to airplanes in different configurations.
Airbus SAS has issued Service Bulletin A330-31-3232, Revision 01, including Appendix 01, dated February 14, 2017. This service information describes procedures for replacement or modification of the FWCs.
This service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
We estimate that this AD affects 105 airplanes of U.S. registry.
We estimate the following costs to comply with this AD:
According to the manufacturer, some of the costs of this AD may be covered under warranty, thereby reducing the cost impact on affected individuals. We do not control warranty coverage for affected individuals. As a result, we have included all costs in our cost estimate.
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes and associated appliances to the Director of the System Oversight Division.
We determined that this AD will not have federalism implications under Executive Order 13132. This AD will 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.
For the reasons discussed above, I certify that this AD:
1. Is not a “significant regulatory action” under Executive Order 12866;
2. Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979);
3. Will not affect intrastate aviation in Alaska; and
4. Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA amends 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
This AD is effective October 5, 2018.
This AD replaces AD 2015-02-17, Amendment 39-18084 (80 FR 4762, January 29, 2015) (“AD 2015-02-17”).
This AD applies to the airplanes identified in paragraphs (c)(1), (c)(2), and (c)(3) of this AD, certificated in any category, all manufacturer serial numbers, except those airplanes with Airbus modification 205228 embodied in production.
(1) Airbus SAS Model A330-201, -202, -203, -223, and -243 airplanes.
(2) Airbus SAS Model A330-223F and -243F airplanes.
(3) Airbus SAS Model A330-301, -302, -303, -321, -322, -323, -341, -342, and -343 airplanes.
Air Transport Association (ATA) of America Code 24, Electrical power.
This AD was prompted by an electrical load analysis that revealed that hydraulic power might not be sufficient to supply the constant speed motor/generator (CSM/G) during slat/flap extension when only one engine is running and a determination that replacement or modification of the two flight warning computers (FWCs) is necessary to address the identified unsafe condition. We are issuing this AD to prevent such a condition which, in conjunction with the loss of the main electrical system, could lead to the scenario where the flight crew is not clearly warned that the electrical system has switched on the battery and thus has a limited duration that would allow a safe landing.
Comply with this AD within the compliance times specified, unless already done.
This paragraph restates the requirements of paragraph (g) of AD 2015-02-17, with a new exception. Except for airplanes identified in paragraph (h) of this AD: Within 15 days after February 13, 2015 (the effective date of AD 2015-02-17), revise the Emergency Procedures section of the Airbus A330/A340 AFM to include the information in the applicable Airbus temporary revision (TR) specified in paragraph (g)(1) or (g)(2) of this AD. This may be done by inserting a copy of the applicable TR specified in paragraph (g)(1) or (g)(2) of this AD into the AFM. Operate the airplane according to the procedures in the applicable TR. When the information in the applicable TR has been included in the general revisions of the AFM, the general revisions may be inserted into the AFM, provided the relevant information in the general revision is identical to that in the TR, and the TR may be removed.
(1) For airplanes in Airbus pre-modification 47930 configuration and pre-Airbus Service Bulletin A330-28-3067 configuration: Airbus A330/A340 AFM TR TR427, UPDATE OF ELEC—EMER CONFIG PROCEDURE, Issue 1.0, dated November 7, 2014.
(2) For airplanes in Airbus post-modification 47930 configuration or post-Airbus Service Bulletin A330-28-3067 configuration: Airbus A330/A340 AFM TR TR428, UPDATE OF ELEC—EMER CONFIG PROCEDURE, Issue 1.0, dated November 7, 2014.
Airplanes operated with an AFM that incorporates the information in Airbus EMERGENCY PROCEDURES/24-ELECTRICAL POWER/ELEC—EMER CONFIG Documentary Unit (DU) 00005218.0001001 (for airplanes in Airbus pre-modification 47930 configuration and pre-Airbus Service Bulletin A330-28-3067 configuration), or DU 00005218.0002001 (for airplanes in an Airbus post-modification 47930 configuration or post-Airbus Service Bulletin A330-28-3067 configuration), as applicable, are compliant with the requirements of paragraph (g) of this AD, provided that the applicable DU is not removed from the AFM.
(1) For the purposes of this AD, an affected FWC is an FWC standard lower than T7-0. An FWC that is not affected is an FWC standard T7-0 having part number (P/N) LA2E20202T70000, or higher standard.
(2) For the purposes of this AD: Group 1 airplanes are those equipped with an affected FWC (as defined in paragraph (i)(1) of this AD) as of the effective date of this AD. Group 2 airplanes are those equipped with FWCs that are not affected (as defined in paragraph (i)(1) of this AD) as of the effective date of this AD.
For Group 1 airplanes: Within 24 months after the effective date of this AD: Replace or modify an affected FWC with an FWC that is not affected, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A330-31-3232, Revision 01, including Appendix 01, dated February 14, 2017.
(1) For Group 1 airplanes: After accomplishing the actions required by paragraph (j) of this AD, no person may install an affected FWC on the modified airplane.
(2) For Group 2 airplanes: As of the effective date of this AD, no person may install an affected FWC on any airplane.
This paragraph provides credit for actions required by paragraph (j) of this AD, if those actions were performed before the effective date of this AD using Airbus Service Bulletin A330-31-3232, dated May 4, 2016.
(1)
(i) Before using any approved AMOC, notify your appropriate principal inspector, or lacking a principal inspector, the manager of the local flight standards district office/certificate holding district office.
(ii) AMOCs approved previously for AD 2015-02-17 are approved as AMOCs for the corresponding provisions of this AD.
(2)
(3)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA AD 2017-0105R1, dated July 17, 2017, for related information. This MCAI may be found in the AD docket on the internet at
(2) For more information about this AD, contact Vladimir Ulyanov, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3229.
(3) Service information identified in this AD that is not incorporated by reference is available at the addresses specified in paragraphs (o)(5) and (o)(6) of this AD.
(1) The Director of the Federal Register approved the incorporation by reference (IBR) of the service information listed in this paragraph under 5 U.S.C. 552(a) and 1 CFR part 51.
(2) You must use this service information as applicable to do the actions required by this AD, unless this AD specifies otherwise.
(3) The following service information was approved for IBR on October 5, 2018.
(i) Airbus Service Bulletin A330-31-3232, Revision 01, including Appendix 01, dated February 14, 2017.
(ii) Reserved.
(4) The following service information was approved for IBR on of February 13, 2015 (80 FR 4762, January 29, 2015).
(i) Airbus A330/A340 Airplane Flight Manual (AFM) Temporary Revision TR427, UPDATE OF ELEC—EMER CONFIG PROCEDURE, Issue 1.0, dated November 7, 2014.
(ii) Airbus A330/A340 AFM Temporary Revision TR428, UPDATE OF ELEC—EMER CONFIG PROCEDURE, Issue 1.0, dated November 7, 2014.
(5) For service information identified in this AD, contact Airbus SAS, Airworthiness Office—EAW, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
(6) You may view this service information at the FAA, Transport Standards Branch, 2200 South 216th St., Des Moines, WA. For information on the availability of this material at the FAA, call 206-231-3195.
(7) You may view this service information that is incorporated by reference 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:
Federal Aviation Administration (FAA), Department of Transportation (DOT).
Final rule.
We are adopting a new airworthiness directive (AD) for certain Airbus SAS Model A318, A319, and A320 series airplanes, and Model A321-111, -112, -131, -211, -212, -213, -231, -232, -251N, -253N, and -271N airplanes. This AD was prompted by a determination that more restrictive maintenance requirements and airworthiness limitations are necessary. This AD requires revising the maintenance or inspection program, as applicable, to incorporate the specified maintenance requirements and airworthiness limitations. We are issuing this AD to address the unsafe condition on these products.
This AD is effective October 5, 2018.
The Director of the Federal Register approved the incorporation by reference of a certain publication listed in this AD as of October 5, 2018.
For service information identified in this final rule, contact Airbus SAS, Airworthiness Office—EIAS, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
You may examine the AD docket on the internet at
Sanjay Ralhan, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3223.
We issued a notice of proposed rulemaking (NPRM) to amend 14 CFR part 39 by adding an AD that would apply to certain Airbus SAS Model A318, A319, and A320 series airplanes, and Model A321-111, -112, -131, -211, -212, -213, -231, -232, -251N, -253N, and -271N airplanes. The NPRM published in the
We are issuing this AD to address the failure of certain life-limited parts, which could result in reduced structural integrity of the airplane.
The European Aviation Safety Agency (EASA), which is the Technical Agent for the Member States of the European Union, has issued EASA Airworthiness Directive 2017-0215, dated October 24, 2017 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for all Airbus SAS Model A318, A319, and A320 series airplanes, and Model A321-111, -112, -131, -211, -212, -213, -231, -232, -251N, -253N, and -271N airplanes. The MCAI states:
The airworthiness limitations for Airbus A320 family aeroplanes, which are approved by EASA, are currently defined and published in the A318, A319, A320 and A321 Airworthiness Limitations Section (ALS) document(s). The Safe Life Airworthiness Limitation Items are specified in ALS Part 1. These instructions have been identified as mandatory for continued airworthiness.
Failure to accomplish these instructions could result in an unsafe condition.
Previously, EASA issued AD 2012-0008 [which corresponds to FAA AD 2015-05-02, Amendment 39-18112 (80 FR 15152, March 23, 2015) (“AD 2015-05-02”)] to require the implementation of the airworthiness limitations as specified in Airbus A318/A319/A320/A321 ALS Part 1 Revision 02, and EASA AD 2014-0141 [which corresponds to FAA AD 2015-22-08, Amendment 39-18313 (80 FR 68434, November 5, 2015) (“AD 2015-22-08”)] to require the implementation of specific life limits for the main landing gear (MLG) upper cardan pin Part Number (P/N) 201163620.
Since those ADs were issued, studies were conducted in the frame of in-service events or during life extension campaigns, the results of which prompted revision of the life limits of several components installed on A320 family aeroplanes. Consequently, Airbus successively issued Revision 03, Revision 04 and Revision 05 of the A318/A319/A320/A321 ALS Part 1. ALS Part 1 Revision 05 also includes the life limits required by EASA AD 2014-0141. A318/A319/A321 ALS Part 1 Revision 05 issue 02 was issued to provide clarifications.
For the reason described above, this [EASA] AD retains the requirements of EASA AD 2012-0008 and EASA AD 2014-0141, which are superseded, and requires accomplishment of the actions specified in A318/A319/A320/A321 ALS Part 1 Revision 05.
You may examine the MCAI in the AD docket on the internet at
We gave the public the opportunity to participate in developing this final rule. We received no comments on the NPRM or on the determination of the cost to the public.
We reviewed the relevant data and determined that air safety and the public interest require adopting this final rule as proposed except for minor editorial changes. We have determined that these minor changes:
• Are consistent with the intent that was proposed in the NPRM for addressing the unsafe condition; and
• Do not add any additional burden upon the public than was already proposed in the NPRM.
Airbus SAS has issued Airbus A318/A319/A320/A321 Airworthiness Limitations Section (ALS) Part 1 Safe Life Airworthiness Limitations (SL-ALI), Revision 05, Issue 02, dated April 19, 2017. This service information describes new maintenance requirements and airworthiness limitations. This service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
We estimate that this AD affects 1,250 airplanes of U.S. registry.
We estimate the following costs to comply with this AD:
We have determined that revising the maintenance or inspection program takes an average of 90 work-hours per operator, although we recognize that this number may vary from operator to operator. In the past, we have estimated that this action takes 1 work-hour per airplane. Since operators incorporate maintenance or inspection program changes for their affected fleet(s), we have determined that a per-operator estimate is more accurate than a per-airplane estimate. Therefore, we estimate the total cost per operator to be $7,650 (90 work-hours × $85 per work-hour).
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes and associated appliances to the Director of the System Oversight Division.
This AD will not have federalism implications under Executive Order 13132. This AD will 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.
For the reasons discussed above, I certify that this AD:
(1) Is not a “significant regulatory action” under Executive Order 12866,
(2) Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979),
(3) Will not affect intrastate aviation in Alaska, and
(4) Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA amends 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
This AD is effective October 5, 2018.
This AD affects AD 2015-05-02, Amendment 39-18112 (80 FR 15152, March 23, 2015) (“AD 2015-05-02”) and AD 2015-22-08, Amendment 39-18313 (80 FR 68434, November 5, 2015) (“AD 2015-22-08”).
This AD applies to the Airbus SAS airplanes identified in paragraphs (c)(1) through (c)(4) of this AD, certificated in any category, with an original certificate of airworthiness or original export certificate of airworthiness issued on or before April 19, 2017.
(1) Model A318-111, -112, -121, and -122 airplanes.
(2) Model A319-111, -112, -113, -114, -115, -131, -132, and -133 airplanes.
(3) Model A320-211, -212, -214, -216, -231, -232, -233, -251N, and -271N airplanes.
(4) Model A321-111, -112, -131, -211, -212, -213, -231, -232, -251N, -253N, and -271N airplanes.
Air Transport Association (ATA) of America Code 05, Time Limits/Maintenance Checks.
This AD was prompted by a determination that more restrictive maintenance requirements and airworthiness limitations are necessary. We are issuing this AD to address the failure of certain life-limited parts, which could result in reduced structural integrity of the airplane.
Comply with this AD within the compliance times specified, unless already done.
Within 90 days after the effective date of this AD, revise the maintenance or inspection program, as applicable, to incorporate Airbus A318/A319/A320/A321 Airworthiness Limitations Section (ALS) Part 1 Safe Life Airworthiness Limitations (SL-ALI), Revision 05, Issue 02, dated April 19, 2017. The initial compliance times for new or revised tasks are at the applicable times specified in Airbus A318/A319/A320/A321 ALS Part 1 Safe Life Airworthiness Limitations (SL-ALI), Revision 05, Issue 02, dated April 19, 2017, or within 90 days after the effective date of this AD, whichever occurs later.
After the maintenance or inspection program has been revised as required by paragraph (g) of this AD, no alternative actions (
Accomplishing the actions required by this AD terminates all requirements of AD 2015-05-02 and AD 2015-22-08.
The following provisions also apply to this AD:
(1)
(2)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA AD 2017-0215, dated October 24, 2017, for related information. This MCAI may be found in the AD docket on the internet at
(2) For more information about this AD, contact Sanjay Ralhan, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3223.
(1) The Director of the Federal Register approved the incorporation by reference (IBR) of the service information listed in this
(2) You must use this service information as applicable to do the actions required by this AD, unless this AD specifies otherwise.
(i) Airbus A318/A319/A320/A321 Airworthiness Limitations Section (ALS) Part 1 Safe Life Airworthiness Limitations (SL-ALI), Revision 05, Issue 02, dated April 19, 2017.
(ii) Reserved.
(3) For service information identified in this AD, contact Airbus SAS, Airworthiness Office—EIAS, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
(4) You may view this service information at the FAA, Transport Standards Branch, 2200 South 216th St., Des Moines, WA. For information on the availability of this material at the FAA, call 206-231-3195.
(5) You may view this service information that is incorporated by reference 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:
Federal Aviation Administration (FAA), Department of Transportation (DOT).
Final rule.
We are adopting a new airworthiness directive (AD) for certain ATR-GIE Avions de Transport Régional Model ATR42-200, -300, and -320 airplanes. This AD was prompted by a determination that more restrictive maintenance instructions and airworthiness limitations are necessary. This AD requires updating the maintenance or inspection program, as applicable, to incorporate new or more restrictive maintenance requirements and airworthiness limitations. We are issuing this AD to address the unsafe condition on these products.
This AD is effective October 5, 2018.
The Director of the Federal Register approved the incorporation by reference of a certain publication listed in this AD as of October 5, 2018.
For service information identified in this final rule, contact ATR-GIE Avions de Transport Régional, 1 Allée Pierre Nadot, 31712 Blagnac Cedex, France; telephone +33 (0) 5 62 21 62 21; fax +33 (0) 5 62 21 67 18; email
You may examine the AD docket on the internet at
Shahram Daneshmandi, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3220.
We issued a notice of proposed rulemaking (NPRM) to amend 14 CFR part 39 by adding an AD that would apply to certain ATR-GIE Avions de Transport Régional Model ATR42-200, -300, and -320 airplanes. The NPRM published in the
The European Aviation Safety Agency (EASA), which is the Technical Agent for the Member States of the European Union, has issued EASA AD 2017-0221R1, dated December 15, 2017 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for all ATR-GIE Avions de Transport Régional Model ATR42-200, -300, and -320 airplanes. The MCAI states:
The airworthiness limitations and certification maintenance requirements (CMR) for ATR aeroplanes, which are approved by EASA, are currently defined and published in the ATR42-200/-300/-320 Time Limits (TL) document. These instructions have been identified as mandatory for continued airworthiness.
Failure to accomplish these instructions could result in an unsafe condition.
Consequently, ATR published Revision 8 of the ATR42-200/-300/-320 TL document, which contains new and/or more restrictive CMRs and airworthiness limitation tasks.
For the reasons described above, this [EASA] AD requires accomplishment of the actions specified in the ATR42-200/-300/-320 TL document Revision 8, hereafter referred to as `the TLD' in this [EASA] AD.
This [EASA] AD, in conjunction with two other [EASA] ADs related to ATR 42-400/-500 (EASA AD 2017-0222) and ATR 72-101/-102/-201/-202/-211/-212/-212A (EASA AD 2017-0223) aeroplanes, retains the requirements of EASA AD 2009-0242 [which corresponds to FAA AD 2008-04-19 R1, Amendment 39-16069 (74 FR 56713, November 3, 2009) (“AD 2008-04-19 R1”)] and EASA AD 2012-1093 [which corresponds to FAA AD 2015-26-09, Amendment 39-18357 (81 FR 1483, January 13, 2016) (“AD 2015-26-09”)]. EASA plans, when all these three ADs are effective, to cancel EASA AD 2009-0242 and EASA AD 2012-0193.
This [EASA] AD is revised to provide the correct issue date (17 October 2016) of the TLD. The original [EASA] AD inadvertently referenced the EASA approval date for that document.
You may examine the MCAI in the AD docket on the internet at
We gave the public the opportunity to participate in developing this final rule. We received no comments on the NPRM or on the determination of the cost to the public.
We reviewed the relevant data and determined that air safety and the
• Are consistent with the intent that was proposed in the NPRM for addressing the unsafe condition; and
• Do not add any additional burden upon the public than was already proposed in the NPRM.
ATR-GIE Avions de Transport Régional has issued ATR42-200/-300/-320, Time Limits Document (TL), Revision 8, dated October 17, 2016. This service information describes life limits and maintenance requirements for the affected airplanes. This service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
We estimate that this AD affects 33 airplanes of U.S. registry.
We estimate the following costs to comply with this AD.
We have determined that revising the maintenance or inspection program takes an average of 90 work-hours per operator, although we recognize that this number may vary from operator to operator. In the past, we have estimated that this action takes 1 work-hour per airplane. Since operators incorporate maintenance or inspection program changes for their affected fleet(s), we have determined that a per-operator estimate is more accurate than a per-airplane estimate. Therefore, we estimate the total cost per operator to be $7,650 (90 work-hours × $85 per work-hour).
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes and associated appliances to the Director of the System Oversight Division.
This AD will not have federalism implications under Executive Order 13132. This AD will 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.
For the reasons discussed above, I certify that this AD:
(1) Is not a “significant regulatory action” under Executive Order 12866,
(2) Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979),
(3) Will not affect intrastate aviation in Alaska, and
(4) Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA amends 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
This AD is effective October 5, 2018.
This AD affects the ADs specified in paragraphs (b)(1), (b)(2), and (b)(3) of this AD.
(1) AD 2000-17-09, Amendment 39-11883 (65 FR 53897, September 6, 2000) (“AD 2000-17-09”).
(2) AD 2008-04-19 R1, Amendment 39-16069 (74 FR 56713, November 3, 2009) (“AD 2008-04-19 R1”).
(3) AD 2015-26-09, Amendment 39-18357 (81 FR 1483, January 13, 2016) (“AD 2015-26-09”).
This AD applies to ATR-GIE Avions de Transport Régional Model ATR42-200, -300, and -320 airplanes, certificated in any category, with an original airworthiness certificate or original export certificate of airworthiness dated on or before October 17, 2016.
Air Transport Association (ATA) of America Code 05, Time limits/maintenance checks.
This AD was prompted by a determination that more restrictive maintenance instructions and airworthiness limitations are necessary. We are issuing this AD to prevent reduced structural integrity of the airplane.
Comply with this AD within the compliance times specified, unless already done.
Within 90 days after the effective date of this AD, revise the maintenance or inspection program, as applicable, to incorporate the information specified in the Airworthiness Limitations (ALS) and Certification Maintenance Requirements (CMR) sections of ATR ATR42-200/-300/-320, Time Limits Document (TL), Revision 8, dated October 17, 2016. The initial compliance time for accomplishing the tasks is at the applicable times specified in the ALS and CMR sections of ATR ATR42-200/-300/-320, Time Limits Document (TL), Revision 8, dated October 17, 2016, or within 90 days after the effective date of this AD, whichever occurs later, except as specified in paragraph (h) of this AD.
For the CMR tasks listed in figure 1 to paragraph (h) of this AD, the initial compliance time for accomplishing the tasks is at the applicable time specified in the ALS and CMR sections of ATR ATR42-200/-300/-320, Time Limits Document (TL), Revision 8, dated October 17, 2016, or within the compliance time specified in figure 1 to paragraph (h) of this AD, whichever occurs later.
After the maintenance or inspection program, as applicable, has been revised as required by paragraph (g) of this AD, no alternative actions (
Accomplishing the actions required by this AD terminates all requirements of AD 2000-17-09, AD 2008-04-19 R1, and AD 2015-26-09 for ATR—GIE Avions de Transport Régional Model ATR42-200, -300, and -320 airplanes only.
The following provisions also apply to this AD:
(1)
(2)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA AD 2017-0221R1, dated December 15, 2017, for related information. This MCAI may be found in the AD docket on the internet at
(2) For more information about this AD, contact Shahram Daneshmandi, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 980198; telephone and fax 206-231-3220.
(1) The Director of the Federal Register approved the incorporation by reference (IBR) of the service information listed in this paragraph under 5 U.S.C. 552(a) and 1 CFR part 51.
(2) You must use this service information as applicable to do the actions required by this AD, unless this AD specifies otherwise.
(i) ATR ATR42-200/-300/-320, Time Limits Document (TL), Revision 8, dated October 17, 2016.
(ii) Reserved.
(3) For service information identified in this AD, contact ATR-GIE Avions de Transport Régional, 1 Allée Pierre Nadot, 31712 Blagnac Cedex, France; telephone +33 (0) 5 62 21 62 21; fax +33 (0) 5 62 21 67 18; email
(4) You may view this service information at the FAA, Transport Standards Branch, 2200 South 216th St., Des Moines, WA. For information on the availability of this material at the FAA, call 206-231-3195.
(5) You may view this service information that is incorporated by reference 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:
Securities and Exchange Commission.
Final rule.
The Securities and Exchange Commission (“Commission”) is revising regulations with respect to the delegations of authority to the Commission's General Counsel. The revisions are a result of the Commission's experience with its existing rules and increase the efficiency of the adjudicatory process.
This rule is effective August 31, 2018.
Brian J. Wong, Senior Counsel, and Benjamin L. Schiffrin, Associate General Counsel, Office of the General Counsel, (202) 551-5150, Securities and Exchange Commission, 100 F Street NE, Washington, DC 20549.
The Commission is revising the delegations of authority to its General Counsel as a result of the Commission's experience with its existing rules and to increase the efficiency of the adjudicatory process. The changes make available to that process the resources of the Office of the General Counsel in timely disposing of procedural and other prehearing matters that are typically of a routine or non-controversial nature. Congress has authorized such delegation by Public Law 87-592, 76 Stat. 394, 15 U.S.C. 78d-1(a), which provides that the Commission “shall have the authority to delegate, by published rule or order, any of its functions to . . . an employee or employee board, including functions with respect to hearing, determining, ordering, certifying, reporting, or
Accordingly, the Commission is amending its rules to delegate authority to the General Counsel to determine procedural requests and other non-dispositive, prehearing matters with respect to administrative proceedings conducted pursuant to the Securities Act of 1933, 15 U.S.C. 77a
The Commission does not delegate to the General Counsel functions with respect to issuing subpoenas, authorizing depositions, ruling upon the admissibility of evidence or upon motions to quash or to compel, presiding over a hearing or the taking of testimony, sanctioning a party, acting upon a dispositive motion, declaring a default, disposing of a claim or defense, or otherwise resolving or terminating the proceeding on the merits. This rule also does not affect the delegation of functions with respect to administrative proceedings conducted before an administrative law judge or other hearing officer, proceedings in which an initial or recommended decision has been issued, or proceedings in which a final order of the Commission has been issued.
With respect to any proceeding in which the Chairman or the General Counsel has determined that separation of functions requirements or other circumstances would make inappropriate the General Counsel's exercise of such functions, those functions are delegated to the Secretary of the Commission. Notwithstanding this delegation, the General Counsel may submit any matter he or she believes appropriate to the Commission. Furthermore, any action made by the General Counsel pursuant to delegated authority would be subject to Commission review as provided by Rules 430 and 431 of the Commission's Rules of Practice, 17 CFR 201.430-201.431 and 15 U.S.C. 78d-1(b). Additionally, being of an inherently preliminary and interlocutory nature, any such action may be revisited by the Commission, on its own initiative or on request of a party, at any time before the Commission's issuance of a final order resolving the proceeding.
The Commission finds, in accordance with the Administrative Procedure Act (“APA”), 5 U.S.C. 553(b)(3)(A), that these revisions relate solely to agency organization, procedures, or practice and do not constitute a substantive rule. Accordingly, the APA's provisions regarding notice of rulemaking, opportunity for public comment, and advance publication of the amendments prior to their effective date are not applicable. These changes are therefore effective on August 31, 2018. For the same reason, and because these amendments do not affect the rights or obligations of non-agency parties, the provisions of the Small Business Regulatory Enforcement Fairness Act, 5 U.S.C. 804(3)(C), are not applicable. Additionally, the provisions of the Regulatory Flexibility Act, 5 U.S.C. 601
This rule is adopted pursuant to statutory authority granted to the Commission, including Section 19 of the Securities Act, 15 U.S.C. 77s; Sections 4A, 4B, and 23 of the Exchange Act, 15 U.S.C. 78d-1, 78d-2, and 78w; Section 38 of the Investment Company Act, 15 U.S.C. 80a-37; Section 211 of the Investment Advisers Act, 15 U.S.C. 80b-11; and Section 3 of the Sarbanes-Oxley Act of 2002, 15 U.S.C. 7202.
Administrative practice and procedure, Authority delegations (government agencies).
For the reasons set out in the preamble, the Commission is amending Title 17, Chapter II of the Code of Federal Regulations as follows:
15 U.S.C. 77c, 77o, 77s, 77z-3, 77sss, 78d, 78d-1, 78d-2, 78o-4, 78w, 78
(d) The functions otherwise delegated to the General Counsel under § 200.30-14(i), with respect to any proceeding in which the Chairman or the General Counsel has determined, pursuant to § 200.30-14(j), that separation of functions requirements or other circumstances would make inappropriate the General Counsel's exercise of such delegated functions.
The addition and revisions read as follows.
(i)(1) With respect to a proceeding conducted pursuant to the Securities Act of 1933, 15 U.S.C. 77a
(i) To determine procedural requests or similar prehearing matters; and
(ii) To rule upon non-dispositive, prehearing motions.
(2) Provided, however, that the General Counsel may not issue subpoenas, authorize depositions, rule upon the admissibility of evidence or upon motions to quash or to compel, preside over a hearing or the taking of testimony, sanction a party, act upon a dispositive motion, declare a default, dispose of a claim or defense, or otherwise resolve or terminate the proceeding on the merits.
(j) Notwithstanding anything in paragraph (i) of this section, the functions described in paragraph (i) of this section are not delegated to the General Counsel with respect to proceedings in which the Chairman or the General Counsel determines that separation of functions requirements or other circumstances would make inappropriate the General Counsel's exercise of such delegated functions. With respect to such proceedings, such functions are delegated to the Secretary of the Commission pursuant to § 200.30-7.
(k) Notwithstanding anything in paragraphs (g) or (i) of this section, in any case described in paragraphs (g) or (i) of this section in which the General Counsel believes it appropriate, he or she may submit the matter to the Commission.
By the Commission.
Tennessee Valley Authority.
Final rule.
The Tennessee Valley Authority (TVA) is publishing a final rule to amend its regulations that govern floating cabins located on the Tennessee River and its tributaries. The mooring of floating cabins on the TVA reservoir system has increased, and TVA has determined that this poses an unacceptable risk to navigation, safety, and the environment. Left unaddressed, floating cabins convert the public waters under TVA's management to private use. The amendments re-define nonnavigable houseboats and floating cabins using one term—“floating cabins”—and prohibit new floating cabins on TVA-managed reservoirs after December 16, 2016. The amendments also include limited mooring standards, limitations on expansions of floating cabins, and requirements for owners to register their floating cabins. Additional health, safety, and environmental standards for floating cabins will be addressed in a later rulemaking once TVA has had the opportunity to discuss such standards with various stakeholders.
In addition, and separate from the updated rule amendments for floating cabins, these amendments contain minor changes to clarify when TVA will allow some water-use facilities (
This final rule is effective October 1, 2018.
David B. Harrell, 865-632-1327; Email:
This final rule is promulgated under the authority of the TVA Act, as amended, 16 U.S.C. 831-831ee, Title V of the Independent Offices Appropriations Act of 1955, 31 U.S.C. 9701, and OMB Circular No. A-25. Under Section 26a of the TVA Act, no obstructions affecting navigation, flood control, or public lands or reservations shall be constructed, operated, or maintained across, along, or in the Tennessee River System without TVA's approval. TVA has long considered nonnavigable structures such as floating cabins to be obstructions that require its approval. In addition, Section 9b of the TVA Act provides that TVA “may establish regulations to prevent the construction of new floating cabins.” 16 U.S.C. 831h-3(e).
TVA is a multi-purpose federal agency that has been charged by Congress with promoting the wise use and conservation of the resources of the Tennessee Valley region, including the Tennessee River System. In carrying out this mission, TVA operates a system of dams and reservoirs on the Tennessee River and its tributaries for the purpose of navigation, flood control, and power production. Consistent with those purposes, TVA uses the system to improve water quality and water supply and to provide a wide range of public benefits including recreation.
To promote the unified development and regulation of the Tennessee River System, Congress directed TVA to approve obstructions across, along, or in the river system under Section 26a of the TVA Act, as amended. “Obstruction” is a broad term that includes, by way of example, boat docks, piers, boathouses, buoys, floats, boat launching ramps, fills, water intakes, devices for discharging effluents, bridges, aerial cables, culverts, pipelines, fish attractors, shoreline stabilization projects, channel excavations, and nonnavigable houseboats. TVA also owns, as agent for the United States, much of the shoreline and inundated land along and under its reservoir system.
Since 1971, TVA has used its authority under Section 26a to prohibit the mooring on the Tennessee River System of new nonnavigable houseboats that are used primarily for habitation or occupation and not for navigation or water transportation. In particular, TVA amended its regulations in 1971 to prohibit the mooring or anchoring of new nonnavigable houseboats except for those in existence before November 21, 1971. Criteria were established then to identify when a houseboat was considered “navigable” and the conditions under which existing nonnavigable houseboats would be allowed to remain. These criteria were characteristics that TVA determined were indicative of real watercraft;
A “nonnavigable houseboat” under TVA's current regulations is identified as any houseboat not in compliance with the following criteria:
Built on a boat hull or on two or more pontoons;
Equipped with a motor and rudder controls located at a point on the houseboat from which there is forward visibility over a 180-degree range;
Compliant with all applicable state and federal requirements relating to vessels;
Registered as a vessel in the state of principal use; and
State registration numbers clearly displayed on the vessel.
Despite the nonnavigable houseboat prohibition, new nonnavigable houseboats in the form of floating cabins have been moored on TVA reservoirs. TVA estimates that approximately 2,000 floating cabins and older nonnavigable houseboats are now moored on TVA reservoirs. Some developers and owners of these floating cabins have asserted that they are not nonnavigable houseboats because they have been designed to meet the criteria for navigability in TVA's regulations. Whether or not this is true, these floating cabins are designed and used primarily for human habitation at a fixed location rather than for transportation or navigation. These floating cabins are a modern version of the pre-1978 nonnavigable houseboats that TVA addressed in its 1971 and 1978 regulatory actions. They are not in any real sense watercraft, and absent action by TVA, the mooring of floating cabins on TVA reservoirs will continue to increase. Until now, TVA has discouraged the increased mooring of floating cabins without using the full scope of its regulatory authority under the TVA Act.
In determining what action to take, TVA prepared an Environmental Impact Statement (EIS) in accordance with the National Environmental Policy Act. This EIS assesses the environmental and socioeconomic impacts of different policies to address the proliferation of floating cabins and nonnavigable houseboats on TVA's reservoirs. TVA released a draft of this EIS for public comment in June 2015 and held four public meetings and a webinar to provide information about its analyses and to facilitate public involvement. Public reaction to this situation widely varied.
Many members of the general public urged TVA to require the removal of all floating cabins because TVA's reservoirs are public resources and owners of floating cabins are occupying public areas. Floating cabin owners generally supported additional reasonable regulation of their structures but argued against policies requiring their removal because of the investments they have made in the structures. Other commenters had concerns about discharges of black (sewage) and gray (showers, sinks, etc.) water from floating cabins and shock and electrocution risks associated with the electrical connections to floating cabins. Commenting agencies consistently supported better regulation of floating cabins. The final EIS and associated documents can be found at
After considering the comments it received during the EIS process and its analyses of impacts, TVA identified as its preferred policy one that establishes standards for floating cabins to enhance compliance with applicable water quality discharge requirements set by other agencies, adherence to electrical safety codes, and location of floating cabins within identified harbor limits of commercial marinas. Under the preferred policy, the mooring of additional floating cabins would be prohibited on the Tennessee River System of which TVA reservoirs are a part. All existing floating cabins, including nonnavigable houseboats, would have to be removed from the Tennessee River System by January 1, 2036, and be subject to a regulatory program in the interim. On May 5, 2016, the TVA Board of Directors adopted the preferred policy with one exception—the Board changed the removal date to May 5, 2046.
On December 16, 2016, the Water Infrastructure Improvements for the Nation Act (WIIN Act) was enacted by the United States Congress. Title IV Section 5003 related to floating cabins and amended the TVA Act to include Section 9b. This new section of the TVA Act specifically addresses floating cabins and provides that TVA may allow the use of floating cabins where the structure was located on waters under TVA's jurisdiction as of December 16, 2016; and where the owner maintains the structure in accordance with reasonable health, safety, and environmental standards set by the TVA Board of Directors. Section 9b also states that TVA may establish regulations to prevent the construction of new floating cabins and may levy fees to ensure compliance.
Section 9b provides the circumstances under which TVA may require the removal of existing floating cabins;
Section 9b of the TVA Act defines “floating cabin” as a watercraft or other floating structure (1) primarily designed and used for human habitation or occupation; and (2) not primarily designed or used for navigation or transportation on the water. This final rule clarifies the type of structure that TVA will regulate as a floating cabin and updates TVA's regulations to clarify that floating cabins placed on TVA waters after December 16, 2016, are prohibited. The final rule also establishes limited mooring requirements; clarifies limitations on expansions; and requires all owners of floating cabins to register their structures with TVA by January 1, 2020, regardless of whether they already have a Section 26a permit. Although this deadline allows plenty of time for owners to register their floating cabins, TVA encourages owners to begin the registration process without delay. A subsequent rulemaking will address: (1) The permitting process for existing floating cabins; (2) health, safety, and environmental standards; and (3) fees.
To more clearly describe the type of floating structure that TVA regulates, the term “nonnavigable houseboat” will be replaced in TVA's Section 26a regulations with the term “floating cabin,” the term adopted by Congress in the WIIN Act. Floating cabins are structures determined by TVA, in its sole judgment, to be designed and used primarily for human habitation or occupation and not designed or used
1. Whether the structure is usually kept at a fixed mooring point;
2. Whether the structure is actually used on a regular basis for transportation or navigation;
3. Whether the structure has a permanent or continuous connection to the shore for electrical, plumbing, water, or other utility service;
4. Whether the structure has the performance characteristics of a vessel typically used for navigation or transportation on the water;
5. Whether the structure can be readily removed from the water;
6. Whether the structure is used for intermittent or extended human-habitation or occupancy;
7. Whether the structure clearly has a means of propulsion and appropriate power/size ratio;
8. Whether the structure is safe to navigate or use for transportation purposes.
Existing floating cabins,
Separate from the amendments to regulations concerning floating cabins, the final rule would result in a minor change to clarify TVA's intent concerning the size of some water-use facilities (
TVA received 32 comments during the public review period consisting of three letters and 29 emails. This includes one comment that TVA received after the comment-close date, which TVA will include. Comments were received from 28 individuals and four representatives of nongovernmental organizations. The following discussion describes the comments received, provides TVA's response to the comments, and describes changes, if any, made by TVA to the rule based on the comments. Although several of the submitted comments do not pertain to the proposed rule published on January 17, 2018, TVA appreciates the perspectives, interests, and concerns expressed by all commenters.
Some of the comments were outside the scope of this rule and were more germane to the next phase of rulemaking where TVA will address: (1) The permitting process for existing floating cabins; (2) health, safety, and environmental standards; and (3) fees. Since August 2017, TVA has worked with a representative stakeholder group to develop more detailed rules and standards to guide future regulation of floating cabins. TVA expects to publish this second proposed rule and take public comments at a later date in 2018.
TVA has previously established corresponding standards for private residential water use facilities. Subparts C and D of the TVA Section 26a regulations set forth the standards for private water use facilities such as boat docks in substantial detail and restrict these facilities in ways that floating cabins are not restricted. For example, living space or sleeping areas are prohibited; enclosed space is limited to 32 square feet for storage; and toilets, sinks, and electrical appliances are not allowed. Electrical lines and service to private docks must be installed in compliance with all State and local electrical codes (satisfactory evidence of compliance to be provided to TVA upon request); and electrical service must be installed with an electrical disconnect that is located above the 500-year floodplain or flood risk profile whichever is higher, and is accessible during flood events.
Floating cabins raise unique safety concerns because many have electrical service supplied by submerged electrical lines, and many are equipped with household appliances.
Concerning the impact of floating cabins, in its Environmental Impact Statement, TVA used an extensive amount of existing information and additional data collection and analysis to support its finding of potential impacts to human health and the environment from floating cabins. The finding of potential impacts are based on existing information, literature on the known effects on resources, comments by agencies and the public about impacts that they experience, internal TVA resource specialists, and professional judgment. The potential adverse impacts from sewage discharges into public waterways and the risk and potential harm to the public safety from poorly maintained electrical wiring are well established and understood. TVA acknowledged that the severity of current impacts is not well-sourced in available information. For example, TVA states that adverse water quality impacts cannot currently be associated with floating cabins, but available information, including the literature, supports TVA's conclusion that the severity of impacts will increase if the proliferation of floating cabins is not controlled and operating standards are not established. It is appropriate that TVA acts to address such potential impacts before they become severe.
TVA does not promulgate rules for vessels, only for obstructions. Vessels such as factory houseboats and wake board boats are regulated by the States and the U.S. Coast Guard. The States mandate and charge for vessel registration. EPA and the Coast Guard issue rules for the proper handling of sewage and waste from vessels. The Coast Guard regulates the building and manufacturing of recreational boats including houseboats under 33 CFR part 183. This includes regulation of electrical and fuel systems, ventilation, loading capacity, and flotation requirements.
Habitable structures such as floating cabins are subject to the same local, state, and federal laws and ordinances for management of sewage and waste water that apply to residences on land.
The States are responsible for enforcing boating laws, and the Coast Guard regulates the building and manufacturing of recreational boats including houseboats under 33 CFR part 183. This involves areas such as electrical and fuel systems, ventilation, loading capacity, and flotation requirements.
With respect to existing floating cabins that were located on waters under TVA jurisdiction prior to or on December 16, 2016, the WIIN Act prohibits removal for a period of 5 or 15 years from December 16, 2016, depending on whether the existing floating cabin received a TVA permit prior to December 16, 2016. After that, existing floating cabins may remain if: Maintained in compliance with reasonable standards as required by the TVA Board; fees are paid that are necessary and reasonable for ensuring compliance; a Section 26a permit is obtained by the deadline provided in the next phase of rulemaking; and the floating cabin remains in compliance with the terms and conditions of the permit.
TVA does not regulate vessels or enforce boating laws. The States and the U.S. Coast Guard have this responsibility and authority. The Coast Guard regulates the building and manufacturing of recreational boats including houseboats under 33 CFR part 183. This involves areas such as electrical and fuel systems, ventilation, loading capacity, and flotation requirements.
This final rule contains no federal mandates for state, local, or tribal government or for the private sector. TVA has determined it will not have a significant annual effect of $100 million or more or result in expenditures of $100 million in any one year by state, local, or tribal governments or by the private sector. The rule will not have a substantial direct effect on the States or Indian tribes, on the relationship between the Federal Government and the States or Indian tribes, or on the
Under the Regulatory Flexibility Act, 5 U.S.C. 605, TVA is required to prepare a regulatory flexibility analysis unless the head of the agency certifies that the rule will not have a significant economic impact on a substantial number of small entities. The statute defines “small entity” as a “small business,” “small organization” (further defined as a “not-for-profit enterprise”), or a “small governmental jurisdiction.” Most applications for water-use facilities are submitted by residential landowners for personal use. Since residential landowners are not businesses, not-for-profit enterprises, or small governmental jurisdictions, there are relatively few “small entities” affected by TVA's final rule. Moreover, nothing in this rule significantly adds to the cost of applying for and constructing any regulated facility. Accordingly, this rule will not have a significant impact on a substantial number of small entities; no regulatory flexibility analysis is required; and TVA's Chief Executive Officer has made the requisite certification.
This rule contains information collection requirements for registration of floating cabins which have been submitted to the Office of Management and Budget (OMB) for approval. The information collection requirements under this rule will be included by amendment within the Section 26a Permit Application information collection. TVA provided burden information and requested comments on these requirements in the preamble to the proposed rule. No comments directed toward the information collection requirements were received.
The only information collection activity contained in the rule is a requirement that owners of floating cabins register them with TVA. The registration includes: Photographs of the structure, drawings showing the size and shape of the floating cabin and attached structures, such as decks or slips, in reasonable detail; and a completed and signed TVA registration form. The registration form includes the owner's mailing and contact information; the TVA permit or TVA-issued numbers; the mooring location; how the floating cabin is moored; how electrical service is provided; how waste water and sewage is managed; and an owner's signature.
The information is necessary and will be used pursuant to TVA Land Management activities and Section 26a of the Tennessee Valley Authority Act of 1933, as amended, which require TVA to collect information relevant to projects that will impact TVA land and land rights and review and approve plans for the construction, operation, and maintenance of any dam, appurtenant works, or other obstruction affecting navigation, flood control, or public lands or reservations across, along, or in the Tennessee River or any of its tributaries.
Respondents will be the owners of floating cabins. The estimated time to complete a registration is 2 hours. TVA estimates that, in the first year of the floating cabin registration process, the number of responses will increase from 1,500 to 3,700. Accordingly, the estimated burden will increase from 3,000 hours to 7,400 hours in the first year, and then return to about 3,000 hours in following years.
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. TVA will publish a document in the
Administrative practice and procedure, Natural resources, Navigation (water), Rivers, Water pollution control.
For the reasons set out in the preamble, the Tennessee Valley Authority amends 18 CFR part 1304 of the Code of Federal Regulations as follows:
16 U.S.C 831-831ee.
* * * By way of example only, such obstructions may include boat docks, piers, boathouses, buoys, floats, boat launching ramps, fills, water intakes, devices for discharging effluent, bridges, aerial cables, culverts, pipelines, fish attractors, shoreline stabilization projects, channel excavations, and floating cabins as described in § 1304.101. * * *
This subpart prescribes requirements for floating cabins on the Tennessee River System. Floating cabins as applied to this subpart include existing nonnavigable houseboats approved by TVA and other existing structures, whose design and use is primarily for human habitation or occupation and not for navigation or transportation on the water. Floating cabins that were not located or moored on the Tennessee River System on or before December 16, 2016, shall be deemed new floating cabins. New floating cabins are prohibited and subject to the removal provisions of this part and Section 9b of the TVA Act. No new floating cabins shall be moored, anchored, or installed on the Tennessee River System. Floating
The revisions and additions read as follows:
(a)(1) Floating cabins include nonnavigable houseboats approved by TVA on or before December 16, 2016, and other floating structures moored on the Tennessee River System as of this date, and determined by TVA in its sole discretion to be designed and used primarily for human habitation or occupation and not designed and used primarily for navigation or transportation on the water. TVA's judgment will be guided by, but not limited to, the following factors:
(i) Whether the structure is usually kept at a fixed mooring point;
(ii) Whether the structure is actually used on a regular basis for transportation or navigation;
(iii) Whether the structure has a permanent or continuous connection to the shore for electrical, plumbing, water, or other utility service;
(iv) Whether the structure has the performance characteristics of a vessel typically used for navigation or transportation on water;
(v) Whether the structure can be readily removed from the water;
(vi) Whether the structure is used for intermittent or extended human-habitation or occupancy;
(vii) Whether the structure clearly has a means of propulsion, and appropriate power/size ratio;
(viii) Whether the structure is safe to navigate or use for transportation purposes.
(2) That a structure could occasionally move from place to place, or that it qualifies under another federal or state regulatory program as a vessel or boat, are factors that TVA also will consider but would not be determinative. Floating cabins are not recreational vessels to which § 1304.409 applies.
(b)(1) Owners of floating cabins are required to register the floating cabin with TVA before January 1, 2020. Floating cabin owners must submit certain required information with their registration. Registration shall include the following information: Clear and current photographs of the structure; a drawing or drawings showing in reasonable detail the size and shape of the floating cabin (length, width, and height) and attached structures, such as decks or slips (length, width, and height); and a completed and signed TVA registration form. The completed TVA registration form shall include the mailing and contact information of the owner(s); the TVA permit or TVA-issued numbers (when applicable); the mooring location of the floating cabin; how the floating cabin is moored; how electrical service is provided; how waste water and sewage is managed; and an owner's signature.
(2) Existing floating cabins may remain on TVA reservoirs provided they stay in compliance with the rules contained in this part and pay any necessary and reasonable fees levied by TVA to ensure compliance with TVA's regulations. Existing floating cabins must be moored at one of the following locations:
(i) To the bank of the reservoir at locations where the owner of the floating cabin is the owner or lessee (or the licensee of such owner or lessee) of the proposed mooring location provided the floating cabin was moored at such location prior to December 16, 2016;
(ii) At locations described by § 1304.201(a)(1), (2), and (3) provided the floating cabin was moored at such location prior to December 16, 2016;
(iii) To the bank of the reservoir at locations where the owner of the floating cabin obtained written approval from TVA pursuant to subpart A of this part authorizing mooring at such location on or before December 16, 2016; or
(iv) Within the designated and approved harbor limits of a commercial marina that complies with § 1304.404. As provided in § 1304.404, TVA may adjust harbor limits and require relocation of an existing floating cabin within the harbor limits. Accordingly, in the case of relocations that occur after December 16, 2016, an existing floating cabin can relocate only to the harbor limits of a commercial marina that complies with § 1304.404.
(3) All floating cabins must be moored in such a manner as to:
(i) Avoid obstruction of or interference with navigation, flood control, public lands or reservations;
(ii) Avoid adverse effects on public lands or reservations;
(iii) Prevent the preemption of public waters when moored in permanent locations outside of the approved harbor limits of commercial marinas;
(iv) Protect land and landrights owned by the United States alongside and subjacent to TVA reservoirs from trespass and other unlawful and unreasonable uses; and
(v) Maintain, protect, and enhance the quality of the human environment.
(d) Existing floating cabins shall be maintained in a good state of repair and may be maintained without additional approval from TVA. Existing floating cabins may be rebuilt to the same configuration, total footprint, and dimensions (length, width, and height) as permitted without additional TVA approval. Owners are required to notify TVA thirty days in advance and submit their proposed plans for rebuilding the floating cabin. Within thirty days of completion, owners must submit a photo of the rebuilt floating cabin for TVA's records. Any expansion in length, width, or height is prohibited, except as approved in writing by TVA and necessary to comply with health, safety, and environmental requirements.
(g) All floating cabins not in compliance with this part are subject to the applicable removal provisions of § 1304.406 and Section 9b of the TVA Act.
The addition and revisions read as follows:
(a) * * * If TVA provided a placard or tag, the tag must be displayed on a
(c) A floating cabin moored at a location approved pursuant to the regulations in this subpart shall not be relocated and moored at a different location without prior approval by TVA, except for movement to a new location within the designated harbor limits of the same commercial dock or marina.
(a) Docks, piers, boathouses, and all other residential water-use facilities shall not exceed a total footprint area of greater than 1,000 square feet, unless the proposed water-use facility will be located in an area of preexisting development. For the purpose of this regulation, “preexisting development” means either: The water-use facility will be located in a subdivision recorded before November 1, 1999, and TVA permitted at least one water-use facility in the subdivision prior to November 1, 1999; or if there is no subdivision, where the water-use facility will be located within a quarter-mile radius of another water-use facility that TVA permitted prior to November 1, 1999. TVA may allow even larger facilities where an applicant requests and justifies a waiver or variance, set forth in §§ 1304.212 and 1304.408 respectively, but such waivers or variances shall be made in TVA's discretion and on a case-by-case basis.
(b) Docks, boatslips, piers, and fixed or floating boathouses are allowable. These and other water-use facilities associated with a lot must be sited within a 1,000- or 1,800-square-foot rectangular or square area as required by § 1304.204(a) at the lakeward end of the access walkway that extends from the shore to the structure. Access walkways to the water-use structure are not included in calculating the 1,000- or 1,800-square foot area.
(n) Except for floating cabins approved in accordance with subpart B of this part, toilets and sinks are not permitted on water-use facilities.
The additions read as follows:
Drug Enforcement Administration, Department of Justice.
Temporary amendment; temporary scheduling order.
The Acting Administrator of the Drug Enforcement Administration is issuing this temporary scheduling order to schedule the synthetic cathinone, 1-(1,3-benzodioxol-5-yl)-2-(ethylamino)-pentan-1-one (
This temporary scheduling order is effective August 31, 2018, until August 31, 2020. If this order is extended or made permanent, the DEA will publish a document in the
Thomas D. Sonnen, Diversion Control Division, Drug Enforcement Administration; Mailing Address: 8701 Morrissette Drive, Springfield, Virginia 22152; Telephone: (202) 598-2896.
Section 201 of the CSA, 21 U.S.C. 811, provides the Attorney General with the authority to temporarily place a substance in schedule I of the CSA for two years without regard to the requirements of 21 U.S.C. 811(b) if he finds that such action is necessary to avoid an imminent hazard to the public safety. 21 U.S.C. 811(h)(1). In addition, if proceedings to control a substance permanently are initiated under 21 U.S.C. 811(a)(1) while the substance is temporarily controlled under section 811(h), the Attorney General may extend the temporary scheduling
Where the necessary findings are made, a substance may be temporarily scheduled if it is not listed in any other schedule under section 202 of the CSA, 21 U.S.C. 812, or if there is no exemption or approval in effect for the substance under section 505 of the Federal Food, Drug, and Cosmetic Act (FDCA), 21 U.S.C. 355. 21 U.S.C. 811(h)(1). The Attorney General has delegated scheduling authority under 21 U.S.C. 811 to the Administrator of the DEA. 28 CFR 0.100.
Section 201(h)(4) of the CSA, 21 U.S.C. 811(h)(4), requires the Administrator to notify the Secretary of the Department of Health and Human Services (HHS) of his intention to temporarily place a substance in schedule I of the CSA.
To find that placing a substance temporarily in schedule I of the CSA is necessary to avoid an imminent hazard to the public safety, the Administrator is required to consider three of the eight factors set forth in 21 U.S.C. 811(c): The substance's history and current pattern of abuse; the scope, duration and significance of abuse; and what, if any, risk there is to the public health. 21 U.S.C. 811(h)(3). Consideration of these factors includes actual abuse, diversion from legitimate channels, and clandestine importation, manufacture, or distribution. 21 U.S.C. 811(h)(3).
A substance meeting the statutory requirements for temporary scheduling may only be placed in schedule I. 21 U.S.C. 811(h)(1). Substances in schedule I are those that have a high potential for abuse, no currently accepted medical use in treatment in the United States, and a lack of accepted safety for use under medical supervision. 21 U.S.C. 812(b)(1).
Available data and information for
Around 2014, the synthetic cathinone,
Available evidence suggests that the history and pattern of abuse of
MDMA or another illicit substance but toxicological analysis revealed that the psychoactive substance was
The identification of
Based on information received by the DEA, the misuse and abuse of
In accordance with 21 U.S.C. 811(h)(3), based on the available data and information, summarized above, the uncontrolled manufacture, distribution, reverse distribution, importation, exportation, conduct of research and chemical analysis, possession, and/or abuse of
In accordance with the provisions of section 201(h) of the CSA, 21 U.S.C. 811(h), the Acting Administrator considered available data and information, herein set forth the grounds for his determination that it is necessary to temporarily schedule
Because the Acting Administrator hereby finds that it is necessary to temporarily place
The CSA sets forth specific criteria for scheduling a drug or other substance. Permanent scheduling actions in accordance with 21 U.S.C. 811(a) are subject to formal rulemaking procedures done “on the record after opportunity for a hearing” conducted pursuant to the provisions of 5 U.S.C. 556 and 557. 21 U.S.C. 811. The permanent scheduling process of formal rulemaking affords interested parties with appropriate process and the government with any additional relevant information needed to make a determination. Final decisions that conclude the permanent scheduling process of formal rulemaking are subject to judicial review. 21 U.S.C. 877. Temporary scheduling orders are not subject to judicial review. 21 U.S.C. 811(h)(6).
Upon the effective date of this temporary order,
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Section 201(h) of the CSA, 21 U.S.C. 811(h), provides for a temporary scheduling action where such action is necessary to avoid an imminent hazard to the public safety. As provided in this subsection, the Attorney General may, by order, schedule a substance in schedule I on a temporary basis. Such an order may not be issued before the expiration of 30 days from (1) the publication of a notice in the
Inasmuch as section 201(h) of the CSA directs that temporary scheduling actions be issued by order and sets forth the procedures by which such orders are to be issued, the DEA believes that the notice and comment requirements of section 553 of the Administrative Procedure Act (APA), 5 U.S.C. 553, do not apply to this notice of intent. In the alternative, even assuming that this notice of intent might be subject to section 553 of the APA, the Acting Administrator finds that there is good cause to forgo the notice and comment requirements of section 553, as any further delays in the process for issuance of temporary scheduling orders would be impracticable and contrary to the public interest in view of the manifest urgency to avoid an imminent hazard to the public safety.
Further, the DEA believes that this temporary scheduling action is not a “rule” as defined by 5 U.S.C. 601(2), and, accordingly, is not subject to the requirements of the Regulatory Flexibility Act (RFA). The requirements for the preparation of an initial regulatory flexibility analysis in 5 U.S.C. 603(a) are not applicable where, as here, the DEA is not required by section 553 of the APA or any other law to publish a general notice of proposed rulemaking.
Additionally, this action is not a significant regulatory action as defined by Executive Order 12866 (Regulatory Planning and Review), section 3(f), and, accordingly, this action has not been
This action 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. Therefore, in accordance with Executive Order 13132 (Federalism) it is determined that this action does not have sufficient federalism implications to warrant the preparation of a Federalism Assessment.
As noted above, this action is an order, not a rule. Accordingly, the Congressional Review Act (CRA) is inapplicable, as it applies only to rules. However, if this were a rule, pursuant to the CRA, “any rule for which an agency for good cause finds that notice and public procedure thereon are impracticable, unnecessary, or contrary to the public interest, shall take effect at such time as the federal agency promulgating the rule determines.” 5 U.S.C. 808(2). It is in the public interest to schedule this substance immediately to avoid an imminent hazard to the public safety. This temporary scheduling action is taken pursuant to 21 U.S.C. 811(h), which is specifically designed to enable the DEA to act in an expeditious manner to avoid an imminent hazard to the public safety. 21 U.S.C. 811(h) exempts the temporary scheduling order from standard notice and comment rulemaking procedures to ensure that the process moves swiftly. For the same reasons that underlie 21 U.S.C. 811(h), that is, the DEA's need to move quickly to place this substance in schedule I because it poses an imminent hazard to the public safety, it would be contrary to the public interest to delay implementation of the temporary scheduling order. Therefore, this order shall take effect immediately upon its publication. The DEA has submitted a copy of this temporary order to both Houses of Congress and to the Comptroller General, although such filing is not required under the Small Business Regulatory Enforcement Fairness Act of 1996 (Congressional Review Act), 5 U.S.C. 801-808 because, as noted above, this action is an order, not a rule.
Administrative practice and procedure, Drug traffic control, Reporting and recordkeeping requirements.
For the reasons set out above, the DEA amends 21 CFR part 1308 as follows:
21 U.S.C. 811, 812, 871(b), 956(b), unless otherwise noted.
(h) * * *
(36)
Coast Guard, DHS.
Notice of deviation from drawbridge regulation.
The Coast Guard has issued a temporary deviation from the operating schedule that governs the U.S. 70 (Alfred A. Cunningham) Bridge across the Trent River, mile 0.0, at New Bern, NC. The deviation is necessary to accommodate the 30th Annual Bike MS: Historic New Bern Ride. This deviation allows the bridge to remain in the closed-to-navigation position.
This deviation is effective from 8:00 a.m. on September 8, 2018 to 9:30 a.m. on September 9, 2018.
The docket for this deviation, [USCG-2018-0841], is available at
If you have questions on this temporary deviation, call or email Ms. Kashanda Booker, Bridge Administration Branch Fifth District, Coast Guard, telephone (757) 398-6227, email
The event director, Game On Inc., with approval from the North Carolina Department of Transportation, who owns and operates the U.S. 70 (Alfred A. Cunningham) Bridge across the Trent River, mile 0.0, at New Bern, NC, has requested a temporary deviation from the current operating regulations. This temporary deviation is necessary to accommodate participation by cyclists during the 30th Annual Bike MS: Historic New Bern Ride. The bridge is a double bascule bridge and has a vertical clearance in the closed position of 14 feet above mean high water.
The current operating schedule is set out in 33 CFR 117.843(a). Under this temporary deviation, the bridge will be maintained in the closed-to-navigation position from 8:00 a.m. to 9:30 a.m. on September 8th and September 9th 2018. The Trent River is used by a variety of vessels including small commercial vessels and recreational vessels. The Coast Guard has carefully coordinated the restrictions with waterway users in publishing this temporary deviation.
Vessels able to pass through the bridge in the closed position may do so at anytime. There is no immediate alternate route for vessels unable to pass through the bridge in the closed position but the bridge will be able to open for emergencies. The Coast Guard will also inform users of the waterways through our Local and Broadcast Notice to Mariners of the change in operating schedule for the bridge so that vessels can arrange their transits to minimize any impacts caused by this temporary deviation.
In accordance with 33 CFR 117.35(e), the drawbridge must return to its regular operating schedule immediately at the end of the effective period of this temporary deviation. This deviation from the operating regulations is authorized under 33 CFR 117.35.
Coast Guard, DHS.
Notice of deviation from drawbridge regulation.
The Coast Guard has issued a temporary deviation from the operating schedule that governs the US40-322 (Albany Avenue) Bridge across the New Jersey Intracoastal Waterway (NJICW) (Inside Thorofare), mile 70.0, at Atlantic City, NJ. The deviation is necessary to accommodate the free movement of pedestrians and vehicles during the 3rd Annual Iron Man. This deviation allows the bridge to remain in the closed-to-navigation position.
The deviation is effective from 6 a.m. to 4 p.m. on September 23, 2018.
The docket for this deviation [USCG-2018-0840], is available at
If you have questions on this temporary deviation, call or email Mr. Martin Bridges, Bridge Administration Branch Fifth District, Coast Guard, telephone 757-398-6422, email
The event director, DelMoSports, LLC, with approval from the New Jersey Department of Transportation, who owns and operates the US40-322 (Albany Avenue) Bridge across the NJICW (Inside Thorofare), mile 70.0, at Atlantic City, NJ, has requested a temporary deviation from the current operating regulations. This temporary deviation is necessary to accommodate the free movement of pedestrians and vehicles during the 3rd Annual Iron Man. The bridge is a double bascule bridge and has a vertical clearance in the closed position of 10 feet above mean high water.
The current operating schedule is set out in 33 CFR 117.733(f). Under this temporary deviation, the bridge will be maintained in the closed-to-navigation position from 6 a.m. to 4 p.m. on September 23, 2018. The NJICW (Inside Thorofare) is used by recreational vessels. The Coast Guard has carefully coordinated the restrictions with waterway users in publishing this temporary deviation.
Vessels able to pass through the bridge in the closed position may do so at anytime. The bridge will be able to open for emergencies and there is no immediate alternate route for vessels unable to pass through the bridge in the closed position. The Coast Guard will also inform the users of the waterway through our Local and Broadcast Notice to Mariners of the change in operating schedule for the bridge so that vessels can arrange their transits to minimize any impacts caused by the temporary deviation.
In accordance with 33 CFR 117.35(e), the drawbridge must return to its regular operating schedule immediately at the end of the effective period of this temporary deviation. This deviation from the operating regulations is authorized under 33 CFR 117.35.
Coast Guard, DHS.
Notice of deviation from drawbridge regulations.
The Coast Guard has issued a temporary deviation from the operating schedule that governs the Burlington Northern Santa Fe (BNSF) Railway Company swing span bridge across Charenton Canal, mile 0.4, at Baldwin, LA. The deviation is necessary to complete repairs, install a bridge deck, and change out a generator. This deviation allows the bridge to remain in the closed-to-navigation position for 48 hours.
This deviation is effective from 10 p.m. on September 2, 2018 through 10 p.m. on September 4, 2018.
The docket for this deviation, USCG-2018-0812 is available at
If you have questions on this temporary deviation, call or email Ms. Donna Gagliano, Bridge Branch Office, Eighth District, U.S. Coast Guard; telephone 504-671-2128, email
Burlington Northern Santa Fe (BNSF), the owner and operator of the BNSF swing span bridge across Charenton Canal, mile 0.4, at Baldwin, LA, requested a temporary deviation from the swing span drawbridge operating schedule to complete repairs, install a bridge deck, and change out a generator. The bridge has a vertical clearance of 10 feet in the closed-to-navigation position. The current operating schedule is set out in 33 CFR 117.5. The bridge currently opens on signal for the passage of vessels.
This temporary deviation allows the bridge to remain closed-to-navigation position for a 48 hour period from 10 p.m. on September 2, 2018 through 10 p.m. on September 4, 2018. Navigation on the waterway consists mainly of tugs with tows, with some commercial fishing vessels and recreational craft. The bridge will be able to open for emergencies, however, an alternate route is available for mariners through the Berwick Locks. The alternate waterway route takes approximately 45 minutes to transit. The Coast Guard has carefully considered the restrictions with waterway users in publishing this temporary deviation. Due to prior experience, as well as coordination with waterway users, and the alternate route through Berwick Locks, this closure will not have a significant effect on these vessels. The Coast Guard will also inform the waterway users of the change in operating schedule for the bridge through our Local Notice and Broadcast Notices to Mariners so that vessel operators can arrange their transits to minimize any impact caused by this temporary deviation.
In accordance with 33 CFR 117.35(e), the drawbridge must return to its regular operating schedule immediately at the end of each of this temporary deviation. This deviation from the operating regulations is authorized under 33 CFR 117.35.
Coast Guard, DHS.
Temporary final rule.
The Coast Guard is establishing a temporary safety zone on waters of Indian River Bay off Long Neck, DE, from 7:30 p.m. through 8:30 p.m. on September 2, 2018, during the Labor Day Long Neck Style Fireworks Display. The safety zone is necessary to ensure the safety of participant vessels, spectators, and the boating public during the event. This regulation prohibits persons and non-participant vessels from entering, transiting through, anchoring in, or remaining within the safety zone unless authorized by the Captain of the Port (COTP) Delaware Bay or a designated representative.
This rule is effective from 7:30 p.m. through 8:30 p.m. on September 2, 2018.
To view documents mentioned in this preamble as being available in the docket, go to
If you have questions on this rule, call or email MST2 Thomas Welker, U.S. Coast Guard, Sector Delaware Bay, Waterways Management Division; telephone (215) 271-4814, email
The Coast Guard is issuing this temporary rule without prior notice and opportunity to comment pursuant to authority under section 4(a) of the Administrative Procedure Act (APA) (5 U.S.C. 553(b)). This provision authorizes an agency to issue a rule without prior notice and opportunity to comment when the agency for good cause finds that those procedures are “impracticable, unnecessary, or contrary to the public interest.” Under 5 U.S.C. 553(b)(B), the Coast Guard finds that good cause exists for not publishing a notice of proposed rulemaking (NPRM) with respect to this rule because it is impracticable and contrary to the public interest to do so. There is insufficient time to allow for a reasonable comment period prior to the date of the event. The rule must be in force by September 2, 2018, to serve its purpose of ensuring the safety of spectators and the general public from hazards associated with the fireworks display. Hazards include accidental discharge of fireworks, dangerous projectiles, and falling hot embers or other debris.
Under 5 U.S.C. 553(d)(3), the Coast Guard finds that good cause exists for making this rule effective less than 30 days after publication in the
The Coast Guard is issuing this rule under authority in 33 U.S.C. 1231. The Captain of the Port Delaware Bay (COTP) has determined that potential hazards associated with the fireworks display on September 2, 2018, will be a safety concern for anyone within a 100-yard radius of the fireworks barge, which will be anchored in approximate position 38°36′35.93″ N, 075°09′31.00″ NW. This rule is needed to protect persons, vessels and the public within the safety zone during the fireworks display.
This rule establishes a temporary safety zone on the waters of Indian River Bay off Long Neck, NJ during a fireworks display from a barge. The event is scheduled to take place at 7:45 p.m. on September 2, 2018. The safety zone will extend 100 yards around the barge, which will be anchored at approximate position 38°36′35.93″ N, 075°09′31.00″ W. No person or vessel will be permitted to enter, transit through, anchor in, or remain within the safety zone without obtaining permission from the COTP Delaware Bay or a designated representative. If authorization to enter, transit through, anchor in, or remain within the safety zone is granted by the COTP Delaware Bay or a designated representative, all persons and vessels receiving such authorization must comply with the instructions of the COTP Delaware Bay or a designated representative. The Coast Guard will provide public notice of the safety zone by Broadcast Notice to Mariners, and by on-scene actual notice.
We developed this rule after considering numerous statutes and Executive orders related to rulemaking. Below we summarize our analyses based on a number of these statutes and Executive orders, and we discuss First Amendment rights of protestors.
Executive Orders 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. Executive Order 13771 directs agencies to control regulatory costs through a budgeting process. This rule has not been designated a “significant regulatory action,” under Executive Order 12866. Accordingly, this rule has not been reviewed by the Office of Management and Budget (OMB), and pursuant to OMB guidance it is exempt from the requirements of Executive Order 13771.
The impact of this rule is not significant for the following reasons: (1) Although persons and vessels may not enter, transit through, anchor in, or remain within the safety zone without authorization from the COTP Delaware Bay or a designated representative, they may operate in the surrounding area during the enforcement period; (2) persons and vessels will still be able to enter, transit through, anchor in, or remain within the regulated area if authorized by the COTP Delaware Bay or a designated representative; and (3) the Coast Guard will provide advance notification of the safety zone to the local maritime community by Broadcast Notice to Mariners and by on-scene actual notice.
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
While some owners or operators of vessels intending to transit the safety zone may be small entities, for the reasons stated in section V.A above, this rule will not have a significant economic impact on any vessel owner or operator.
Under section 213(a) of the Small Business Regulatory Enforcement Fairness Act of 1996 (Public Law 104-121), we want to assist small entities in understanding this 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
Small businesses may send comments on the actions of Federal employees who enforce, or otherwise determine compliance with, Federal regulations to the Small Business and Agriculture Regulatory Enforcement Ombudsman and the Regional Small Business Regulatory Fairness Boards. The Ombudsman evaluates these actions annually and rates each agency's responsiveness to small business. If you wish to comment on actions by employees of the Coast Guard, call 1-888-REG-FAIR (1-888-734-3247). The Coast Guard will not retaliate against small entities that question or complain about this rule or any policy or action of the Coast Guard.
This rule will 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 Executive Order 13132, Federalism, if it has 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. We have analyzed this rule under that Order and have determined that it is consistent with the fundamental federalism principles and preemption requirements described in Executive Order 13132.
Also, this rule does not have tribal implications under Executive Order 13175, Consultation and Coordination with Indian Tribal Governments, because it does not have a substantial direct effect on one or more Indian tribes, on the relationship between the Federal Government and Indian tribes, or on the distribution of power and responsibilities between the Federal Government and Indian tribes. If you believe this rule has 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 rule will not result in such an expenditure, we do discuss the effects of this rule elsewhere in this preamble.
We have analyzed this rule under Department of Homeland Security Directive 023-01 and Commandant Instruction M16475.1D, which guide the Coast Guard in complying with the National Environmental Policy Act of 1969(42 U.S.C. 4321-4370f), and have determined 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 rule involves a safety zone that will prohibit persons and vessels from entering, transiting through, anchoring in, or remaining within a limited area on the navigable water in the Indian River Bay, during a fireworks display lasting approximately one hour. It is categorically excluded from further review under paragraph L60(a) of Appendix A, Table 1 of DHS Instruction Manual 023-01-001-01, Rev. 01. A Record of Environmental Consideration (REC) supporting this determination is 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
Harbors, Marine safety, Navigation (water), Reporting and recordkeeping requirements, Security measures, Waterways.
For the reasons discussed in the preamble, the Coast Guard amends 33 CFR part 165 as follows:
33 U.S.C. 1231; 50 U.S.C. 191; 33 CFR 1.05-1, 6.04-1, 6.04-6, and 160.5; Department of Homeland Security Delegation No. 0170.1.
(a)
(b)
(c)
(2) To seek permission to enter or remain in the zone, contact the COTP or the COTP's representative via VHF-FM channel 16 or 215-271-4807. Those in the safety zone must comply with all lawful orders or directions given to them by the COTP or the COTP's designated representative.
(3) This section applies to all vessels except those engaged in law enforcement, aids to navigation servicing, and emergency response operations.
(d)
(e)
Coast Guard, DHS.
Notice of enforcement of regulation.
The Coast Guard will enforce the temporary safety zone for the 6th Annual Swim for Alligator Reef Lighthouse, Islamorada, Florida from 6:30 a.m. until 4:30 p.m. on September 15, 2018. Our regulation for Recurring Safety Zones in Captain of the Port Key West Zone identifies the regulated area for this event. This action is necessary to ensure the safety of event participants and spectators. During the enforcement period, no person or vessel may enter, transit through, anchor in, or remain within the regulated area without approval from the Captain of the Port Key West or a designated representative.
The regulations in 33 CFR 165.786, Table to § 165.786, Line No. 9.1 will be enforced from 6:30 a.m. until 4:30 p.m. on September 15, 2018.
If you have questions on this notice, call or email Gregory Bergstrom, Sector Key West Waterways Management Department, Coast Guard; telephone (305) 292-8772; email
The Coast Guard will enforce the safety zones in 33 CFR 165.786, Table to § 165.786, Line No. 9.1, from 6:30 a.m. until 4:30 p.m. on September 15, 2018, for the annual Swim for Alligator Reef Lighthouse in Islamorada, Florida. Our regulation for Recurring Safety Zones in Captain of the Port Key West Zone, § 165.786, Line No. 9.1, specifies the location of the regulated area as all within 50 yards in front of the lead safety vessel preceding the first event participants, 50 yards behind the safety vessel trailing the last event participants, and at all times extend 100 yards on either side of the safety vessels.
This action prevents vessels from transiting areas specifically designated as safety zones during the periods of enforcement. During the enforcement period, no person or vessel may enter, transit through, anchor within, or remain within the established regulated areas without approval from the Captain of the Port Key West or designated representative. The Coast Guard may be assisted by other Federal, State, or local law enforcement agencies in enforcing this regulation.
The Coast Guard will provide notice of the regulated area by Local Notice to Mariners and Broadcast Notice to Mariners. If the Captain of the Port Key West determines that the regulated area need not be enforced for the full duration stated in this publication, he or she may use a Broadcast Notice to Mariners to grant general permission to enter the regulated area.
Office of Elementary and Secondary Education, Department of Education.
Correcting amendment.
On August 22, 2018, the Secretary published a final rule amending the Code of Federal Regulations (CFR) by removing outdated or superseded regulations, which are no longer needed for the reasons discussed in the rule. There was a clerical error in one of the amendments that prevented two CFR sections from being removed. This document corrects that error.
This correction is effective August 31, 2018.
Anna Lieth, U.S. Department of Education, 400 Maryland Avenue SW, Room 3W337, Washington, DC 20202. Telephone: (202) 453-5682. Email:
If you use a telecommunications device for the deaf (TDD) or a text telephone (TTY), call the Federal Relay Service (FRS), toll free, at 1-800-877-8339.
The Department is correcting a clerical error in an amendment in FR Rule Doc. No. 2018-17480, which published on August 22, 2018, at 83 FR 42440. The rule removed outdated or superseded regulations in 34 CFR parts 200, 237, and 299. One of the amendments to part 200 intended to remove §§ 200.55 through 200.57. The heading to the amendment reflected that section span but its corresponding instruction (instruction 8) directed the removal of § 200.57 only. This document correctly removes §§ 200.55 and 200.56 as originally intended in the August 22, 2018, rule.
Education of disadvantaged, Elementary and secondary education, Grant programs-education, Indians-education, Infants and children, Juvenile delinquency, Migrant labor, Private schools, Reporting and recordkeeping requirements.
For reasons discussed in the preamble, the Secretary correctly amends 34 CFR part 200 as follows:
20 U.S.C. 6301 through 6576, unless otherwise noted.
Environmental Protection Agency (EPA).
Final rule.
The Environmental Protection Agency (EPA) is approving a state implementation plan (SIP) revision submission from Maryland addressing the infrastructure requirements of section 110 of the Clean Air Act (CAA) for the 2012 annual fine particulate matter (PM
This final rule is effective on October 1, 2018.
EPA has established a docket for this action under Docket ID Number EPA-R03-OAR-2017-0441. All documents in the docket are listed on the
Sara Calcinore, (215) 814 2043, or by email at
Particle pollution, also referred to as particulate matter (PM), is a complex mixture of small particles and liquid droplets suspended in the air, which causes adverse health effects and is the leading cause of visibility impairment in the United States. Particles with a diameter equal to or less than 2.5 microns, referred to as fine particulate matter or PM
On July 18, 1997, EPA promulgated a new 24-hour and a new annual NAAQS for PM
Pursuant to section 110(a)(1), states must submit “within 3 years (or such shorter period as the Administrator may prescribe) after the promulgation of a national primary ambient air quality standard (or any revision thereof),” a plan that provides for the “implementation, maintenance, and enforcement” of such NAAQS. The statute directly imposes on states the duty to make these SIP submissions and the requirements to make the submissions is not conditioned upon EPA's taking any action other than promulgating a new or revised NAAQS. Section 110(a)(2) includes a list of specific elements that “[e]ach such plan” submission must address. EPA commonly refers to such state plans as “infrastructure SIPs.”
On August 18, 2016, the State of Maryland, through the Maryland Department of the Environment (MDE), formally submitted a SIP revision (SIP #16-12) in order to satisfy the requirements of section 110(a) of the CAA for the 2012 PM
Maryland's infrastructure SIP submittal did not address the following two elements of CAA section 110(a)(2): The portion of section 110(a)(2)(C) pertaining to permit programs, known as nonattainment new source review (NNSR), under part D of the CAA, and section 110(a)(2)(I), referred to as “element (I),” pertaining to the nonattainment requirements of part D, title I of the CAA. According to the EPA guidance issued on September 13, 2013 (2013 Infrastructure Guidance),
On July 5, 2018 (83 FR 31352), EPA published a notice of proposed rulemaking (NPR) for Maryland. In the NPR, EPA proposed approval of Maryland's August 18, 2016 infrastructure SIP submittal for the 2012 PM
EPA received a total of three comments on the July 5, 2018 NPR. Two of the comments did not concern any of the specific issues raised in the NPR, nor did they address EPA's rationale for the proposed approval of MDE's submittal. Therefore, EPA is not responding to those comments. EPA also received a comment that was supportive of EPA's proposed approval of Maryland's August 18, 2016 infrastructure SIP submittal for the 2012 PM
EPA's review of Maryland's August 18, 2016 infrastructure SIP submittal for the 2012 PM
Under the CAA, the Administrator is required to approve a SIP submission that complies with the provisions of the CAA and applicable federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). Thus, in reviewing SIP submissions, EPA's role is to approve state choices, provided that they meet the criteria of the CAA. Accordingly, this action merely approves state law as meeting federal requirements and does not impose additional requirements beyond those imposed by state law. For that reason, this action:
• Is not a “significant regulatory action” subject to review by the Office of Management and Budget under Executive Orders 12866 (58 FR 51735, October 4, 1993) and 13563 (76 FR 3821, January 21, 2011);
• Is not an Executive Order 13771 (82 FR 9339, February 2, 2017) regulatory action because
SIP approvals are exempted under Executive Order 12866.
• does not impose an information collection burden under the provisions of the Paperwork Reduction Act (44 U.S.C. 3501
• is certified as not having a significant economic impact on a substantial number of small entities under the Regulatory Flexibility Act (5 U.S.C. 601
• does not contain any unfunded mandate or significantly or uniquely affect small governments, as described in the Unfunded Mandates Reform Act of 1995 (Pub. L. 104-4);
• does not have federalism implications as specified in Executive Order 13132 (64 FR 43255, August 10, 1999);
• is not an economically significant regulatory action based on health or safety risks subject to Executive Order 13045 (62 FR 19885, April 23, 1997);
• is not a significant regulatory action subject to Executive Order 13211 (66 FR 28355, May 22, 2001);
• is not subject to requirements of Section 12(d) of the National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272 note) because application of those requirements would be inconsistent with the CAA; and
• does not provide EPA with the discretionary authority to address, as appropriate, disproportionate human health or environmental effects, using practicable and legally permissible methods, under Executive Order 12898 (59 FR 7629, February 16, 1994).
In addition, this rule does not have tribal implications as specified by Executive Order 13175 (65 FR 67249, November 9, 2000), because the SIP is not approved to apply in Indian country located in the state, and EPA notes that it will not impose substantial direct costs on tribal governments or preempt tribal law.
The Congressional Review Act, 5 U.S.C. 801
Under section 307(b)(1) of the CAA, petitions for judicial review of this action must be filed in the United States Court of Appeals for the appropriate circuit by October 30, 2018. Filing a petition for reconsideration by the Administrator of this final rule does not affect the finality of this action for the purposes of judicial review nor does it extend the time within which a petition for judicial review may be filed, and shall not postpone the effectiveness of such rule or action. This action approving Maryland's August 18, 2016 infrastructure SIP submittal for the 2012 PM
Environmental protection, Air pollution control, Incorporation by reference, Intergovernmental relations, Nitrogen dioxide, Particulate matter, Reporting and recordkeeping requirements, Sulfur oxides, Volatile organic compounds.
40 CFR part 52 is amended as follows:
42 U.S.C. 7401
(e) * * *
Environmental Protection Agency (EPA).
Final rule.
The Environmental Protection Agency (EPA) is approving certain changes to the Michigan State Implementation Plan (SIP). This action relates to changes to the Permit To Install (PTI) requirements of Part 2 of the Michigan Administrative Code (Part 2 Rules). Changes to the Part 2 Rules were submitted on November 12, 1993; May 16, 1996; April 3, 1998; September 2, 2003; March 24, 2009; and February 28, 2017.
This final rule is effective on October 1, 2018.
EPA has established a docket for this action under Docket ID No. EPA-R05-OAR-2007-1092. All documents in the docket are listed on the
Rachel Rineheart, Environmental Engineer, Air Permits Section, Air Programs Branch (AR-18J), Environmental Protection Agency, Region 5, 77 West Jackson Boulevard, Chicago, Illinois 60604, (312) 886-7017,
Throughout this document whenever “we,” “us,” or “our” is used, we mean EPA. This supplementary information section is arranged as follows:
The State of Michigan's minor source PTI rules are contained in Part 2 of the Michigan Administrative Code. EPA last approved changes to the Part 2 rules in 1982. The Michigan Department of Environmental Quality (MDEQ) has submitted several Part 2 revision packages since that time; however, EPA has not taken a final action on any of the submittals. The following table provides a summary of the various state submittals with the most recent version of each section of the Michigan Rule highlighted in bold.
EPA published a proposed approval of all changes, except the public notice procedures in Michigan R. 336.1205, on August 15, 2017 (82 FR 38651), with a 30-day public comment period. EPA reopened the comment period twice due to missing files in the docket on
Section 110(a)(2)(C) of Clean Air Act (the Act) requires that each SIP include a program to provide for the regulation of construction and modification of stationary sources as necessary to assure that the National Ambient Air Quality Standards (NAAQS) are achieved. Specific elements for an approvable construction permitting plan are found in the implementing regulations at 40 CFR part 51, subpart I—Review of New Sources and Modifications. Requirements relevant to minor construction programs are 40 CFR 51.160-51.164. EPA regulations have few specific criteria for state minor new source review (NSR) programs. Generally, state programs must set forth legally enforceable procedures that allow the state to prevent any planned construction activity that would result in a violation of the state's SIP or a national standard.
The revisions to Part 2 submitted by MDEQ are largely provisions that strengthen the already approved minor NSR program adding greater detail with respect to applicability, required application material, and processing of applications; however, the revisions do include changes to waiver provisions
EPA received several comments during the public comment process. EPA received four anonymous comments that were unrelated to the action, and we will not be addressing those comments. EPA received adverse comment on the proposed approval from the Sierra Club, the Great Lakes Environmental Law Center, the Center for Biological Diversity, and the Environmental Law & Policy Center. EPA received a letter from the Environmental Law & Policy Center dated September 14, 2017, and a letter from the Sierra Club, Great Lakes Environmental Law Center, and the Center for Biological Diversity dated September 14, 2017, during the original public comment period. Sierra Club and the Great Lakes Environmental Law Center provided additional comment during the first reopening in a letter dated December 4, 2017. Sierra Club, the Great Lakes Environmental Law Center, and the Center for Biological Diversity provided additional comments during the second reopening in a letter dated January 24, 2018. A summary of the comments received and EPA's response follow.
Michigan R. 336.1201a gives the MDEQ the ability to create general PTIs. A general permit is a permit document that contains standardized requirements that multiple stationary sources can use. It may cover categories of emission units or stationary sources that are similar in nature. The purpose of a general permit is to ensure the protection of air quality while simplifying the permit process for similar minor sources. General permits allow the permitting authority to notify the public through one notice that it intends to apply those requirements to any eligible source that seeks coverage under the permit in the future. This minimizes the burden on the reviewing authority's resources by eliminating the need to issue separate permits for each individual minor source within the source type or category covered by the general permit. Use of a general permit also decreases the time required for an individual minor source to obtain a preconstruction permit because the application process is standardized.
Michigan R. 336.1201a allows MDEQ to issue general PTIs for categories of similar emission units or stationary sources. The rule requires the general permits to contain limitations as necessary to assure compliance with applicable requirements, and that limitations on potential to emit be enforceable as a practical matter. The general permits must also identify the criteria by which a stationary source or emission unit may qualify for the permit. Finally, the rule requires MDEQ to provide for public notice of the general permit.
Michigan R. 336.1202 provides the MDEQ with the authority to grant a waiver from the requirement to obtain a permit prior to commencing construction in certain limited circumstances. The PSD provisions of the Act prohibit commencement of construction without first obtaining the required permit authorizing construction; however, the requirement only applies to major sources, and no such restriction is specified under the minor NSR program requirements set forth in 40 CFR 51.160. In addition, EPA has made determinations which further support that limited construction may begin before a permit is issued for minor sources. For example, EPA's October 10, 1978, memorandum from Edward E. Reich to Thomas W. Devine in Region 1 discusses limited preconstruction activities allowed at a site with both PSD and non-PSD sources. This memo states that construction may begin on PSD-exempt projects before the permit is issued. EPA has established its position that limited waivers are acceptable for true minor sources in previous rulemaking. (See 68 FR 2217 and 73 FR 12893.) As stated previously, the minor NSR provisions at 40 CFR 51.160 require state programs to determine if activities would violate an applicable SIP or national standard and to prevent construction of an activity that would violate an applicable SIP provision or national standard. Michigan R 336.1202(1) requires an application for a waiver be submitted to MDEQ and requires MDEQ to act on the request within 30 days. Construction may not proceed unless the waiver is granted. The rule also indicates that the waiver does not guarantee approval of the required PTI and any construction activity would be at the owner/operator's risk. Michigan R. 336.1202(2) limits the waiver to minor construction activities (
Michigan R. 336.1209 allows a source to rely on a permit to install or a permit to operate issued by MDEQ before May 6, 1980 (prior to approval in the SIP), or issued by Wayne county before a delegation of authority to Wayne county pursuant to state statute for the purposes of applicability to Michigan R. 336.1210. Michigan R. 336.1210 is the state's Title V operating permit program.
Michigan R. 336.1278 and 336.1278a work together to define the scope of the permit exemptions in Michigan R. 336.1280 through 336.1290 and to ensure that sources choosing to forgo a case-by-case permitting decision collect and maintain data necessary to demonstrate that any construction related activities qualified for the exemptions. Michigan R. 336.1278 excludes major activities subject to either the PSD or major non-attainment programs from using the exemptions. This rule also affirms that the exemptions only apply to the requirement to obtain a construction permit and that all other applicable requirements including existing permit limitations must be met. Michigan R. 336.1278a requires sources using an exemption to maintain records that demonstrate the applicability of the exemption including information such as a description of equipment installed, date of installation, identification of the specific exemption being applied and an analysis that the exemption exclusions in Michigan R. 336.1278 do not apply.
Michigan R. 336.1280-R. 336.1290 define the specific categories of exemptions.
Michigan R. 336.1285(2)(a) exempts “routine maintenance, parts replacement, or other repairs that are considered by the department to be minor, or relocation of process equipment within the same geographical site not involving any appreciable change in the quality, nature, quantity, or impact of the emission of an air contaminant therefrom.” The rule also includes examples of changes that would be covered by the exemption. These examples help to define the scope of changes MDEQ intended the exemption to cover. EPA specifically noted concerns with this exemption in a November 9, 1999, proposed disapproval. This exemption is part of the approved SIP. Michigan had made some fairly minor changes such as changing the word “commission” to “Department.” The only substantive change was the addition of the word “routine.” Because it might be interpreted as defining “routine maintenance, repair and replacement” under the major source permitting rules, EPA was concerned that the ambiguity might lead to sources inappropriately applying the exemption to major source permitting. There have been significant changes to the structure of MDEQ's major source permitting rules since 1999. At that time, PSD permits were issued pursuant to a delegation of 40 CFR 52.21 through the general requirements of the Part 2 rules. The state's major non-attainment permitting rules were also included in Part 2 at that time. MDEQ now has a SIP approved PSD program, and the major source permitting requirements have been moved to separate sections of the Michigan Administrative Code. The PSD rules are in Part 18 and the major NSR rules are in Part 19. EPA believes the previously listed concerns are effectively addressed by the requirements of Michigan R. 336.1278 and 336.1278a in conjunction with the move of major source applicability criteria to separate rule sections.
Michigan R. 336.1285(2)(b) exempts “changes in a process or process equipment which do not involve installing, constructing, or reconstructing an emission unit and which do not involve any meaningful change in the quality and nature or any meaningful increase in the quantity of the emission of an air contaminant therefrom.”
Michigan R. 336.1285(2)(c) exempts the following changes from minor construction permitting:
“Changes in a process or process equipment that do not involve installing, constructing, or reconstructing an emission unit and that involve a meaningful change in the quality and nature or a meaningful increase in the quantity of the emission of an air contaminant resulting from any of the following:
(i) Changes in the supplier or supply of the same type of virgin fuel, such as coal, no. 2 fuel oil, no. 6 fuel oil, or natural gas.
(ii) Changes in the location, within the storage area, or configuration of a material storage pile or material handling equipment.
(iii) Changes in a process or process equipment to the extent that such changes do not alter the quality and nature, or increase the quantity, of the emission of the air contaminant beyond the level which has been described in and allowed by an approved permit to install, permit to operate, or order of the department.”
Michigan R. 336.1285(2)(d) exempts the replacement or reconstruction of air pollution control equipment with equivalent or more efficient control equipment. Michigan R. 336.1285(2)(e) exempts the installation of control equipment required by a National Emission Standard for Hazardous Air Pollutants. Michigan R. 336.1285(2)(f) exempts the installation and construction of air pollution control equipment that does not result in a significant increase in a pollutant from the pollution controls.
EPA received several comments regarding the 110(l) analysis provided by MDEQ. Section 110(l) of the CAA states that “[t]he Administrator shall not approve a revision of a plan if the revision would interfere with any applicable requirement concerning attainment and reasonable further progress or any other applicable requirement of this chapter.” 42 U.S.C. 7410(l). EPA does not interpret section 110(l) to require a full attainment or maintenance demonstration before any changes to a SIP may be approved. Generally, a SIP revision may be approved under section 110(l) if EPA finds it will at least preserve status quo air quality. See
In considering the new exemptions in Michigan R. 336.1280 through Michigan R. 336.1290, EPA examined the emission projections provided by MDEQ in the 2003 and 2017 submittals, the structure of the existing SIP permitting rules and the structure of each new exemption, and in some cases conservative air quality analysis (modeling or qualitative analysis in the case of ozone) provided in the 2017 submittal. MDEQ's currently approved permitting SIP generally requires a PTI for any change resulting in an increase in a regulated pollutant unless the particular change falls into one of the categories of exemptions contained in Michigan R. 336.1280 through Michigan R. 336.1290. MDEQ's revisions expand the exempt categories. Several of the exempt categories would have no associated emissions of criteria pollutants. Several other categories of
Approximately a week before the end of the first comment period for this rulemaking, EPA was informed of issues with the electronic docket at
In comments received during the first reopening, commenters noted that the electronic file for the September 2003 submittal from MDEQ was missing an attachment. The missing information was added to the electronic docket in November of 2017, and the interested parties were informed that EPA would reopen the comment period for a second time for a period of 15 days. The second reopening of the comment period was published on January 9, 2017. EPA believes that the correction of the
The comments received during the first reopening also noted that EPA had included copies of several MDEQ policy documents to the docket. The commenters noted that if EPA is proposed to approve any of these documents as part of the SIP, EPA must issue a revised proposed rulemaking making clear to the public which documents it is proposing to approve. EPA is not approving these documents into the SIP and the summary of documents EPA is incorporating into the SIP in Section VI “Incorporation by Reference” in the proposed rulemaking is correct. The policy documents were added because EPA thought they would be of interest to the public. EPA is not relying on these documents to support approval of the rules, and there is no need to re-propose based on the addition of these documents to the docket as suggested by the commenters.
EPA is approving all changes submitted by MDEQ except for changes to Michigan R 336.1205 which includes provisions for public notice. EPA will not be taking any action with respect to the changes in public notice and will be addressing Michigan R 336.1205 in a separate action. The already approved public notice procedures will remain in the SIP until EPA takes action on Michigan R 336.1205.
In this rule, EPA is finalizing regulatory text that includes incorporation by reference. In accordance with requirements of 1 CFR 51.5, EPA is finalizing the incorporation by reference of the Michigan Regulations described in the amendments to 40 CFR part 52 set forth below. EPA has made, and will continue to make, these documents generally available through
Under the Act, the Administrator is required to approve a SIP submission that complies with the provisions of the Act and applicable Federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). Thus, in reviewing SIP submissions, EPA's role is to approve state choices, provided that they meet the criteria of the Act. Accordingly, this action merely approves state law as meeting Federal requirements and does not impose additional requirements beyond those imposed by state law. For that reason, this action:
• Is not a significant regulatory action subject to review by the Office of Management and Budget under Executive Orders 12866 (58 FR 51735, October 4, 1993) and 13563 (76 FR 3821, January 21, 2011);
• Is not an Executive Order 13771 (82 FR 9339, February 2, 2017) regulatory action because SIP approvals are exempted under Executive Order 12866;
• Does not impose an information collection burden under the provisions of the Paperwork Reduction Act (44 U.S.C. 3501
• Is certified as not having a significant economic impact on a substantial number of small entities under the Regulatory Flexibility Act (5 U.S.C. 601
• Does not contain any unfunded mandate or significantly or uniquely affect small governments, as described in the Unfunded Mandates Reform Act of 1995 (Pub. L. 104-4);
• Does not have Federalism implications as specified in Executive Order 13132 (64 FR 43255, August 10, 1999);
• Is not an economically significant regulatory action based on health or safety risks subject to Executive Order 13045 (62 FR 19885, April 23, 1997);
• Is not a significant regulatory action subject to Executive Order 13211 (66 FR 28355, May 22, 2001);
• Is not subject to requirements of Section 12(d) of the National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272 note) because application of those requirements would be inconsistent with the Act; and
• Does not provide EPA with the discretionary authority to address, as appropriate, disproportionate human health or environmental effects, using practicable and legally permissible methods, under Executive Order 12898 (59 FR 7629, February 16, 1994).
In addition, the SIP is not approved to apply on any Indian reservation land or in any other area where EPA or an Indian tribe has demonstrated that a tribe has jurisdiction. In those areas of Indian country, the rule does not have tribal implications and will not impose substantial direct costs on tribal governments or preempt tribal law as specified by Executive Order 13175 (65 FR 67249, November 9, 2000).
The Congressional Review Act, 5 U.S.C. 801
Under section 307(b)(1) of the Act, petitions for judicial review of this action must be filed in the United States Court of Appeals for the appropriate circuit by October 30, 2018. Filing a petition for reconsideration by the Administrator of this final rule does not affect the finality of this action for the purposes of judicial review nor does it extend the time within which a petition for judicial review may be filed, and shall not postpone the effectiveness of such rule or action. This action may not be challenged later in proceedings to enforce its requirements. (See section 307(b)(2).)
Environmental protection, Air pollution control, Carbon monoxide, Incorporation by reference, Intergovernmental relations, Lead, Nitrogen dioxide, Ozone, Particulate matter, Reporting and recordkeeping requirements, Sulfur oxides, Volatile organic compounds.
40 CFR part 52 is amended as follows:
42 U.S.C. 7401
(c) * * *
Environmental Protection Agency (EPA).
Final rule.
The Environmental Protection Agency (EPA) is approving a state implementation plan (SIP) revision submitted by the District of Columbia (the District) that pertains to the good neighbor and interstate transport requirements of the Clean Air Act (CAA) for the 2008 ozone national ambient air quality standards (NAAQS). The CAA's good neighbor provision requires EPA and states to address the interstate transport of air pollution that affects the ability of other states to attain and maintain the NAAQS. Specifically, the good neighbor provision requires each state in its SIP to prohibit emissions that will significantly contribute to nonattainment, or interfere with maintenance, of a NAAQS in another state. The District submitted a SIP revision on June 13, 2014 that addresses the interstate transport requirements for the 2008 ozone NAAQS. On July 5, 2018, EPA published a proposed rule for just the good neighbor provision of the District's June 13, 2014 submittal. EPA is approving the District's SIP as having adequate provisions to meet the requirements of the good neighbor provision for the 2008 ozone NAAQS in accordance with section 110 of the CAA.
This final rule is effective on October 1, 2018.
EPA has established a docket for this action under Docket ID Number EPA-R03-OAR-2014-0701. All documents in the docket are listed on the
Ellen Schmitt, (215) 814-5787, or by email at
On June 13, 2014, the District Department of the Environment (DDOE) on behalf of the District submitted a revision to its SIP to satisfy the requirements of section 110(a)(2) of the CAA for the 2008 ozone NAAQS. On April 13, 2015 (80 FR 19538), EPA approved all parts of the District's June 13, 2014 submittal with the exception of the portion of the submittal that addressed section 110(a)(2)(D)(i)(I) of the CAA. Section 110(a)(2)(D)(i)(I), also called the good neighbor provision, consists of two prongs that require that a state's
On July 5, 2018 (83 FR 31350), EPA published a notice of proposed rulemaking (NPR) for the District of Columbia, approving the portion of the June 13, 2014 District SIP revision addressing prongs 1 and 2 of the interstate transport requirements for section 110(a)(2)(D)(i)(I) for the 2008 ozone NAAQS.
In its June 13, 2014 submittal, the District identified the implemented regulations within its SIP that limit nitrogen dioxide (NO
EPA evaluated the District's submittal for the 2008 ozone NAAQS, considering: Ozone precursor emissions; an analysis of District source sectors; and in-place controls and regulations. Due to the District's small number of sources and the high cost of further reductions, EPA proposed in its July 5, 2018 NPR that the District's SIP, as presently approved, contains adequate measures to prevent District sources from interfering with maintenance or contributing significantly to nonattainment in another state for the 2008 ozone NAAQS. The rationale for EPA's proposed action was discussed in greater detail in the NPR and accompanying technical support document (TSD) and will not be restated here.
In this rulemaking action, EPA is approving one portion of the District's June 13, 2014 submittal—the portion addressing prongs 1 and 2 of section 110(a)(2)(D)(i)(I) of the CAA. EPA previously acted on other portions of Delaware's June 13, 2014 SIP submittal for the 2008 ozone NAAQS.
EPA received a total of four anonymous comments on the July 5, 2018 NPR. All of the comments received are included in the docket for this action. Three of the comments did not concern any of the specific issues raised in the NPR, nor did they address EPA's rationale for the proposed approval of the District's submittal. Therefore, EPA is not responding to those comments. EPA did receive one comment considered to be relevant to this rulemaking action.
The commenter indicates that EPA was supposed to take action on the District's SIP revision within 12 months of receiving the SIP submittal. The commenter also indicates the length of time (4 years) it took for EPA to approve the SIP revision from the time of its submittal and questions if transported pollution could have been eliminated if SIP revisions like this one were approved in a timely manner. The commenter asks what air quality and human health impacts the delay of this action has had on neighboring states.
EPA acknowledges that it missed the statutory deadline to take action on the good neighbor portion of the District's June 13, 2014 SIP submittal.
EPA is approving the portion of the June 13, 2014 District SIP revision addressing prongs 1 and 2 of the interstate transport requirements for section 110(a)(2)(D)(i)(I) of the CAA for the 2008 ozone NAAQS.
On April 13, 2015 (80 FR 19538), EPA approved the following infrastructure elements or portions thereof from the June 13, 2014 submittal: CAA section 110(a)(2)(A), (B), (C), (D)(i)(II), (D)(ii), (E), (F), (G), (H), (J), (K), (L), and (M). This action approves the remaining portions of the June 13, 2014 SIP revision, which address prongs 1 and 2 of section 110(a)(2)(D)(i)(I) of the CAA, also known as the good neighbor provision. EPA did not take action upon these elements in the Agency's prior SIP approval action, published on April 13, 2015 (80 FR 19538).
Under the CAA, the Administrator is required to approve a SIP submission that complies with the provisions of the CAA and applicable federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). Thus, in reviewing SIP submissions, EPA's role is to approve state choices, provided that they meet the criteria of the CAA. Accordingly, this action merely approves state law as meeting federal requirements and does not impose additional requirements beyond those imposed by state law. For that reason, this action:
• Is not a “significant regulatory action” subject to review by the Office of Management and Budget under Executive Orders 12866 (58 FR 51735, October 4, 1993) and 13563 (76 FR 3821, January 21, 2011);
• is not an Executive Order 13771 (82 FR 9339, February 2, 2017) regulatory action because SIP approvals are exempted under Executive Order 12866.
• does not impose an information collection burden under the provisions of the Paperwork Reduction Act (44 U.S.C. 3501
• is certified as not having a significant economic impact on a substantial number of small entities under the Regulatory Flexibility Act (5 U.S.C. 601
• does not contain any unfunded mandate or significantly or uniquely affect small governments, as described in the Unfunded Mandates Reform Act of 1995 (Pub. L. 104-4);
• does not have federalism implications as specified in Executive Order 13132 (64 FR 43255, August 10, 1999);
• is not an economically significant regulatory action based on health or safety risks subject to Executive Order 13045 (62 FR 19885, April 23, 1997);
• is not a significant regulatory action subject to Executive Order 13211 (66 FR 28355, May 22, 2001);
• is not subject to requirements of Section 12(d) of the National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272 note) because application of those requirements would be inconsistent with the CAA; and
• does not provide EPA with the discretionary authority to address, as appropriate, disproportionate human health or environmental effects, using practicable and legally permissible methods, under Executive Order 12898 (59 FR 7629, February 16, 1994).
In addition, this rule does not have tribal implications as specified by Executive Order 13175 (65 FR 67249, November 9, 2000), because the SIP is not approved to apply in Indian country located in the state, and EPA notes that it will not impose substantial direct costs on tribal governments or preempt tribal law.
The Congressional Review Act, 5 U.S.C. 801
Under section 307(b)(1) of the CAA, petitions for judicial review of this action must be filed in the United States
Environmental protection, Air pollution control, Incorporation by reference, Nitrogen dioxide, Ozone, Volatile organic compounds.
40 CFR part 52 is amended as follows:
42 U.S.C. 7401
(e) * * *
Environmental Protection Agency (EPA).
Final rule.
The Environmental Protection Agency (EPA) is approving portions of State Implementation Plan (SIP) submissions from Colorado, Montana, North Dakota, South Dakota and Wyoming addressing the Clean Air Act (CAA or Act) interstate transport SIP requirements for the 2010 sulfur dioxide (SO
This rule is effective on October 1, 2018.
The EPA has established a docket for this action under Docket ID Number EPA- EPA-R08-OAR-2018-0109. All documents in the docket are listed on the
Adam Clark, Air Program, U.S. EPA Region 8, Mailcode 8P-AR, 1595 Wynkoop Street, Denver, Colorado 80202-1129, (303) 312-7104, or
Throughout this document “we,” “us” and “our” means the EPA.
On June 4, 2018, the EPA proposed to approve submissions from Colorado, Montana, North Dakota, South Dakota and Wyoming as meeting the interstate transport requirements of CAA section 110(a)(2)(D)(i)(I) for the 2010 SO
The EPA also agrees with NDDH that the 2010 emissions value for North Dakota was incorrect in “Table 1—SO
The EPA notes that North Dakota's comment refers to “nonattainment or maintenance
Regarding the additional information provided by NDDH to support the EPA's proposed conclusion that the state meets the requirements of 110(a)(2)(D)(i)(I) for the 2010 SO
With respect to the assertions WDEQ makes in its comments regarding maintenance areas, the EPA does not interpret the reference to “maintenance” under section 110(a)(2)(D)(i)(I) to be limited to maintenance areas. As previously described, this provision requires evaluation of the potential impact of upwind emissions on
The EPA is approving the following submission as meeting the interstate transport requirements of CAA section 110(a)(2)(D)(i)(I) for the 2010 SO
Under the CAA, the Administrator is required to approve a SIP submission that complies with the provisions of the Act and applicable federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). Thus, in reviewing SIP submissions, the EPA's role is to approve state choices, provided that they meet the criteria of the CAA. Accordingly, this action merely approves state law as meeting federal requirements and do not impose additional requirements beyond those imposed by state law. For that reason, this action:
• Is not a “significant regulatory action” subject to review by the Office of Management and Budget under Executive Orders 12866 (58 FR 51735, October 4, 1993) and 13563 (76 FR 3821, January 21, 2011);
• Is not an Executive Order 13771 (82 FR 9339, February 2, 2017) regulatory action because SIP approvals are exempted under Executive Order 12866;
• Does not impose an information collection burden under the provisions of the Paperwork Reduction Act (44 U.S.C. 3501
• Is certified as not having a significant economic impact on a substantial number of small entities under the Regulatory Flexibility Act (5 U.S.C. 601
• Does not contain any unfunded mandate or significantly or uniquely affect small governments, described in the Unfunded Mandates Reform Act of 1995 (Pub. L. 104-4);
• Does not have federalism implications as specified in Executive Order 13132 (64 FR 43255, August 10, 1999);
• Is not an economically significant regulatory action based on health or safety risks subject to Executive Order 13045 (62 FR 19885, April 23, 1997);
• Is not a significant regulatory action subject to Executive Order 13211 (66 FR 28355, May 22, 2001);
• Is not subject to requirements of section 12(d) of the National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272 note) because application of those requirements would be inconsistent with the CAA; and
• Does not provide the EPA with the discretionary authority to address, as appropriate, disproportionate human health or environmental effects, using practicable and legally permissible methods, under Executive Order 12898 (59 FR 7629, February 16, 1994).
In addition, these SIPs are not approved to apply on any Indian reservation land or in any other area where EPA or an Indian tribe has demonstrated that a tribe has jurisdiction. In those areas of Indian country, the rule does not have tribal implications and will not impose substantial direct costs on tribal governments or preempt tribal law as specified by Executive Order 13175 (65 FR 67249, November 9, 2000).
The Congressional Review Act, 5 U.S.C. 801
Under section 307(b)(1) of the Clean Air Act, petitions for judicial review of this action must be filed in the United States Court of Appeals for the appropriate circuit by October 30, 2018. Filing a petition for reconsideration by the Administrator of this final rule does not affect the finality of this action for the purposes of judicial review nor does it extend the time within which a petition for judicial review may be filed, and shall not postpone the effectiveness of such rule or action. This action may not be challenged later in proceedings to enforce its requirements. (See section 307(b)(2).)
Environmental protection, Air pollution control, Incorporation by reference, Intergovernmental relations, Nitrogen dioxide, Particulate matter, Reporting and recordkeeping
40 CFR part 52 is amended as follows:
42 U.S.C. 7401
(f) Addition to the Colorado State Implementation Plan of the Colorado Interstate Transport SIP regarding 2010 Standards, submitted to EPA on July 17, 2013, and February 16, 2018, for both elements of CAA section 110(a)(2)(D)(i)(I) for the 2010 SO
(e) EPA is approving the Montana 2010 SO
(h) EPA is approving the North Dakota 2010 SO
(e) * * *
(e) * * *
Rural Housing Service, USDA.
Proposed rule.
Through this action, the Rural Housing Service (RHS or Agency) is proposing to amend its regulations for the direct and guaranteed single family housing loan and grant programs.
Comments on the proposed rule must be received on or before October 30, 2018.
You may submit comments to this rule by any of the following methods:
•
Follow the instructions for submitting comments.
•
All written comments will be available for public inspection during regular work hours at the address listed above.
Shannon Chase, Finance and Loan Analyst, Single Family Housing Direct Loan Origination Branch, USDA Rural Development, STOP 0783, 1400 Independence Ave. SW, Washington, DC 20250-0783, Telephone: (515) 305-0399. Email:
The RHS is proposing to amend its regulations for the direct and guaranteed single family housing loan and grant programs in 7 CFR parts 3550 and 3555 by:
(1) Revising the definition of very low-, low-, and moderate-income to allow for a two-tier income limit structure (also known as income banding) within the single family housing direct loan and grant programs.
(2) Clarifying that net family assets are not considered when calculating repayment income, and that net family assets exclude amounts in voluntary retirement accounts, tax advantaged college, health, or medical savings or spending accounts, and other amounts deemed by the Agency not to constitute net family assets.
(3) Revising the methodology used to determine the area loan limits to use a percentage(s), as determined by the Agency, of the applicable local HUD section 203(b) limit.
(4) As a result of income banding, converting borrowers currently receiving payment assistance method 1 to payment assistance method 2 should they receive a subsequent loan.
(5) Revising the definition of low-income to allow for the two-tier income limit structure (income banding) within the single family housing guaranteed loan program.
Section 510(k) of Title V the Housing Act of 1949 (42 U.S.C. 1480(k)), as amended, authorizes the Secretary of Agriculture to promulgate rules and regulations as deemed necessary to carry out the purpose of that title.
The Office of Management and Budget (OMB) has designated this rule as not significant under Executive Order 12866.
This rule has been reviewed under Executive Order 12988, Civil Justice Reform. Except where specified, all State and local laws and regulations that are in direct conflict with this rule will be preempted. Federal funds carry Federal requirements. No person is required to apply for funding under this program, but if they do apply and are selected for funding, they must comply with the requirements applicable to the Federal program funds. This rule is not retroactive. It will not affect agreements entered into prior to the effective date of the rule. Before any judicial action may be brought regarding the provisions of this rule, the administrative appeal provisions of 7 CFR part 11 must be exhausted.
Title II of the Unfunded Mandates Reform Act of 1995 (UMRA), Public Law 104-4, establishes requirements for Federal agencies to assess the effect of their regulatory actions on State, local, and tribal governments and the private sector. Under section 202 of the UMRA, the Agency generally must prepare a written statement, including a cost-benefit analysis, for proposed and final rules with “Federal mandates” that may result in expenditures to State, local, or tribal governments, in the aggregate, or to the private sector, of $100 million, or more, in any one year. When such a statement is needed for a rule, section 205 of the UMRA generally requires the Agency to identify and consider a reasonable number of regulatory alternatives and adopt the least costly, most cost-effective, or least burdensome alternative that achieves the objectives of the rule.
This proposed rule contains no Federal mandates (under the regulatory provisions of Title II of the UMRA) for State, local, and tribal governments or the private sector. Therefore, this rule is not subject to the requirements of sections 202 and 205 of the UMRA.
This document has been reviewed in accordance with 7 CFR part 1970, subpart A, “Environmental Policies.” It is the determination of the Agency that this action does not constitute a major Federal action significantly affecting the quality of the human environment, and, in accordance with the National Environmental Policy Act of 1969, Public Law 91-190, neither an Environmental Assessment nor an Environmental Impact Statement is required.
The policies contained in this rule do not have any substantial direct effect on States, on the relationship between the national government and States, or on the distribution of power and responsibilities among the various levels of government. Nor does this rule impose substantial direct compliance costs on State and local governments. Therefore, consultation with the States is not required.
In compliance with the Regulatory Flexibility Act (5 U.S.C. 601
This program/activity is not subject to the provisions of Executive Order 12372, which require intergovernmental consultation with State and local officials. (See the Notice related to 7 CFR part 3015, subpart V, at 48 FR 29112, June 24, 1983; 49 FR 22675, May 31, 1984; 50 FR 14088, April 10, 1985.)
This executive order imposes requirements in the development of regulatory policies that have tribal implications or preempt tribal laws. RHS has determined that the proposed rule does not have a substantial direct effect on one or more Indian tribe(s) or on either the relationship or the distribution of powers and responsibilities between the Federal Government and the Indian tribes. Thus, this proposed rule is not subject to the requirements of Executive Order 13175.
The following programs, which are listed in the Catalog of Federal Domestic Assistance, are affected by this proposed rule: Number 10.410, Very Low to Moderate Income Housing Loans (specifically the section 502 direct and guaranteed loans), and Number 10.417, Very Low-Income Housing Repair Loans and Grants (specifically the section 504 direct loans and grants).
In accordance with the Paperwork Reduction Act of 1995 (44 U.S.C. 3501
RHS is committed to complying with the E-Government Act, 44 U.S.C. 3601 et. seq., to promote the use of the internet and other information technologies to provide increased opportunities for citizen access to Government information and services, and for other purposes.
In accordance with Federal civil rights law and U.S. Department of Agriculture (USDA) civil rights regulations and policies, the USDA, its Agencies, offices, and employees, and institutions participating in or administering USDA programs are prohibited from discriminating based on race, color, national origin, religion , sex, gender identity (including gender expression), sexual orientation, disability, age, marital status, family/parental status, income derived from a public assistance program, political beliefs, or reprisal or retaliation for prior civil rights activity, in any program or activity conducted or funded by USDA (not all bases apply to all programs). Remedies and complaint filing deadlines vary by program or incident.
Persons with disabilities who require alternative means of communication for program information (
To file a program discrimination complaint, complete the USDA Program Discrimination Complaint Form, AD-3027, found online at
(1)
(2)
(3)
USDA is an equal opportunity provider, employer, and lender.
In order to improve the delivery of the single family housing loan programs and to promote consistency among the programs when appropriate, RHS proposes making the following revisions to 7 CFR parts 3550 and 3555.
(1) Revising the definition of very low-, low-, and moderate-income in § 3550.10 to allow for a two-tier income limit structure (income banding) for the single family housing direct loan and grant programs.
The revisions will help minimize the impact of varying minimum wages among states and territories and the observed disconnect between minimum wages and the low median income in many areas. Under current regulations, the income of a household with two people earning the minimum wage would exceed the low-income eligibility limit in 39 to 93 percent of the counties in 16 states and territories. In other words, under current regulations and income limits, the income from a two-person household earning minimum wage may be considered too high to qualify for a direct loan.
In accordance with Section 501(b)(4) of the Housing Act of 1949 (42 U.S.C. 1471(b)(4)), the terms “low income families or persons” and “very low-income families or persons” mean those families and persons whose income do not exceed the respective levels established for low-income families and very low-income families under the United States Housing Act of 1937 (42 U.S.C. 1437
For the pilot, the Agency used the authority in 42 U.S.C. 1437a(b)(2)(D), which provides for HUD and USDA to consult on income ceilings for rural areas, taking into account the types of programs that will use the income ceilings as well as subsidy characteristics. Based on this authority, the Agency used a two-tier income limit structure for the single family housing programs which bands together 1-4 person households using the 4-person income level set by HUD, and 5-8 person households using the 8-person income level established by HUD. The pilot has successfully served more borrowers, providing meaningful
Such banding has successfully been used to establish the moderate income limits in the guaranteed single family housing loan program for years (the term “moderate income” is not defined in Section 501(b)(4) of the Housing Act of 1949 and therefore is not restricted in the same way as “very low-” and “low-income”).
The Agency has consulted with HUD, and both agencies agree that the two-tier income limit approach is suitable for the USDA single family housing loan and grant programs. The impacted income definitions in § 3550.10 will be revised to simply state that the respective limit is “an adjusted income limit developed in consultation with HUD”. The two-tier income limits will be published annually via a Procedure Notice and posted to the Agency website at
The Agency also proposes to revise the definition of moderate income so that it does not exceed the moderate income limit established for the guaranteed single family housing loan program. The Agency will publish a specific limit in the program handbook.
The revisions to the income definitions will ultimately allow the Agency and HUD to account for the differences between renting (which is the focus of HUD and 42 U.S.C. 1437
(2) Revising § 3550.54(d) to remove the requirement that net family assets be included in the calculation of repayment income.
Currently, net family assets are considered for determining annual income, down payment purposes, and repayment income. The Agency proposes to exclude net family assets from repayment income calculations because repayment income focuses on the income of those who sign the promissory note, whereas net family assets considers the finances of other family members. Net family assets will still be considered for annual income and down payment purposes.
The Agency also proposes to revise the regulation so that the list of net family assets considered for annual income and down payment purposes would exclude amounts in voluntary retirement accounts such as individual retirement accounts (IRAs), 401(k) plans, Keogh accounts, and the cash value of life insurance policies.
In addition, the Agency proposes to exclude the value of tax advantaged college savings plans, the value of tax advantaged health or medical savings or spending accounts, and other amounts deemed by the Agency, from net family assets considered in the determination of annual income and down payments.
Excluding these types of assets when considering annual income or down payment requirements will help safeguard the assets for their intended purposes and promote a healthy financial support system for the household when it does incur education and health care costs, or enters retirement.
The Agency also proposes removing from net family assets the value, in excess of the consideration received, for any business or household assets disposed of for less than the fair market value during the 2 years preceding the income determination. This proposed change recognizes that it is not productive or meaningful to consider assets which have been disposed of in the past.
Lastly, the Agency proposes two minor changes primarily for consistency between the direct and guaranteed single family housing loan regulations. The Agency proposes to include in net family assets any equity in capital investments for consistency with the guaranteed single family housing loan regulations, as well as obtaining a full understanding of an applicant's financial condition before making a decision on a loan. In the exclusions from net family assets, the Agency proposes to change the language from “American Indian trust land” to “American Indian restricted land”. The terms “trust land” and “restricted” are often used interchangeably, and the proposed revision is for consistency between the direct and guaranteed program regulations, and will not result in any substantive changes.
(3) Revising the methodology used to determine the area loan limits in § 3550.63(a) to use a percentage(s), as determined by the Agency, of the applicable local HUD section 203(b) limit.
The revisions to the area loan limit methodology will streamline the determination of area loan limits and improve the reliability of the data set used to establish the area loan limits. The current process to annually establish the area loan limits uses a data set based on overly restrictive nationalized parameters and requires a significant amount of staff time on all levels (field, state, and national). Currently, § 3550.63(a) allows for two methods that a State Director may use to establish area loan limits. The first option is based on the cost to construct a modest home plus the market value of an improved lot based on recent sales data. The second option allows the State Director to use State Housing Authority (SHA) limits as long as the limit is within 10 percent of the cost data plus the market value of the improved lot. This second option is rarely used because the SHA limits are usually not within the 10 percent limit.
For the first option, the most widely used option, the Agency contracts with a third party that provides building cost data for real estate valuations to obtain construction costs, but those construction costs are based on parameters for homes that do not reflect the varied modest homes available to program borrowers. In addition, obtaining the market value is a time-consuming process relying on collecting and updating recent home sales data, which is particularly difficult given Agency staff appraiser shortages over the past few years.
The Agency has been operating a pilot to test the alternate methodology of basing the area loan limits on a percentage of the FHA Forward One-Family mortgage limits (the HUD 203(b) limit). Under the pilot, 80 percent of the HUD 203(b) limit was used to establish the area loan limits in selected pilot states. The 80 percent was established based on a side-by-side, county-by-county comparison of the Agency's existing area loan limits to various percentages of the HUD 203(b) limits. It was determined that 80 percent of the HUD 203(b) limits was adequate to cover the loan amounts in the majority of states (vs. lower percentages of 60-70 percent).
While the pilot states generally experienced increases in their area loan limits, the increases were not significant, in part because an applicant's qualification amount continues to be limited to repayment ability, property eligibility criteria (for example, properties financed through the program are currently subject to 2,000 square feet), and other factors. Average loan amounts in the pilot states increased 13.4 percent from Fiscal Year 2015 to 2017, while average loan amounts in the non-pilot states have increased 5.4 percent during the same period.
The Agency believes the higher percent increase in the pilot states is acceptable for several reasons. For example, the alternate methodology makes new construction under the program more feasible, and new
The Agency will determine the percentage(s) based on housing market conditions and trends, and publish the percentage(s) in the program handbook. The resulting area loan limits will be posted to the Agency website at
(4) Revising § 3550.68(b)(2) to convert a borrower currently receiving payment assistance method 1 to payment assistance method 2 should that borrower receive a subsequent loan.
The proposed change is related to the income banding proposal, as payment assistance method 2 will more closely align the subsidy with what is actually needed for affordability. The proposed change avoids potentially over-subsidizing borrowers using payment assistance method 1 under the income banding system, and reduces the potential for negative impacts to the program's subsidy rate.
(5) Revising the definition of low-income in § 3555.10 for the single family housing guaranteed loan program to allow for the two-tier income limit structure (income banding) discussed above. The two-tier income limits will be published annually via a Procedure Notice and posted to the Agency website at
The single family housing guaranteed loan program provides guarantees to lenders who make loans to low- and moderate-income borrowers in rural areas who are without sufficient resources or credit to obtain a loan without the guarantee. As mentioned, the guaranteed loan program already uses the two-tier income limit structure for moderate income limits. The proposed change would allow the two-tier income limit structure to be used for determining the very low- and low-income limits in the guaranteed loan program.
Administrative practice and procedure, Environmental impact statements, Fair housing, Grant programs—housing and community development, Housing, Loan programs—housing and community development, Low and moderate income housing, Manufactured homes, Reporting and recordkeeping requirements, Rural areas.
For the reasons stated in the preamble, 7 CFR parts 3550 and 3555 are proposed to be amended as follows:
5 U.S.C. 301; 42 U.S.C. 1480(k).
The revisions and additions read as follows:
(d) Net family assets. Income from net family assets must be included in the calculation of annual income. * * *
(1) Net family assets include, but are not limited to:
(i) Equity in real property or other capital investments, other than the dwelling or site;
(iv) Stocks, bonds, and other forms of capital investments that are accessible to the applicant without retiring or terminating employment;
(v) Lump sum receipts such as lottery winnings, capital gains, inheritances; and
(vi) Personal property held as an investment.
(2) * * *
(i) Interest in American Indian restricted land;
(v) Amounts in voluntary retirement plans such as individual retirement accounts (IRAs), 401(k) plans, and Keogh accounts (except at the time interest assistance is initially granted);
(vi) The value of an irrevocable trust fund or any other trust over which no member of the household has control;
(vii) Cash value of life insurance policies;
(viii) The value of tax advantaged college savings plans (529 plan, Coverdell Education Savings Account, etc.);
(ix) The value of tax advantaged health or medical savings or spending accounts; and
(x) Other amounts deemed by the Agency not to constitute net family assets.
(a) * * *
(1) The area loan limit is the maximum value of the property RHS will finance in a given locality. This limit is based on a percentage(s) of the applicable local HUD section 203(b) limit. The percentage(s) will be determined by the Agency and published in the program handbook. The area loan limits will be reviewed at least annually and posted to the Agency website.
(i) [Removed]
(ii) [Removed]
(iii) [Removed]
(iv) [Removed]
(v) [Removed]
(b) * * *
(2) If a borrower receiving payment assistance using payment assistance method 1 received a subsequent loan, payment assistance method 2 will be used to calculate the subsidy for the initial loan and subsequent loan.
5 U.S.C. 301; 42 U.S.C. 1480(k).
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
We propose to adopt a new airworthiness directive (AD) for certain The Boeing Company Model 787-8 and 787-9 airplanes. This proposed AD was prompted by a determination that certain areas in the tire/wheel threat zones could be susceptible to damage, which could result in loss of braking on one main landing gear (MLG) truck, loss of nose wheel steering, and loss of directional control on the ground when below rudder effectiveness speed. This proposed AD would require installing hydraulic tubing, a pressure-operated check valve, and new flight control software. We are proposing this AD to address the unsafe condition on these products.
We must receive comments on this proposed AD by October 15, 2018.
You may send comments, using the procedures found in 14 CFR 11.43 and 11.45, by any of the following methods:
•
•
•
•
For service information identified in this NPRM, contact Boeing Commercial Airplanes, Attention: Contractual & Data Services (C&DS), 2600 Westminster Blvd., MC 110-SK57, Seal Beach, CA 90740-5600; telephone 562-797-1717; internet
You may examine the AD docket on the internet at
Kelly McGuckin, Aerospace Engineer, Systems and Equipment Section, FAA, Seattle ACO Branch, 2200 South 216th Street, Des Moines, WA 98198; phone and fax: 206-231-3546; email:
We invite you to send any written relevant data, views, or arguments about this proposal. Send your comments to an address listed under the
We will post all comments we receive, without change, to
Boeing determined that certain areas in the tire/wheel threat zones could be susceptible to damage due to a thrown tire tread or tire burst. This could result in a loss of braking on one MLG truck, loss of nose wheel steering, and loss of directional control on the ground when below rudder effectiveness speed. The Model 787 hydraulic system is configured with a reserve steering system intended to maintain the nose wheel steering function in the event that a thrown tire tread or tire burst leads to a brake system failure such that differential braking cannot be used for directional control. Boeing has determined that damage from a MLG thrown tire tread or tire burst event could also result in the loss of the reserve steering system, resulting in loss of directional control on the ground and consequent runway excursion.
We reviewed Boeing Alert Service Bulletins B787-81205-SB290032-00 and B787-81205-SB290033-00, both Issue 001, both dated November 17, 2017. This service information describes procedures for installing hydraulic tubing and installing a pressure-operated check valve. These documents are distinct since they apply to different airplane models.
We also reviewed Boeing Alert Service Bulletin B787-81205-SB270039-00, Issue 002, dated March 8, 2018. This service information describes procedures for installing new flight control software.
This service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
We are proposing this AD because we evaluated all the relevant information and determined the unsafe condition described previously is likely to exist or develop in other products of the same type design.
This proposed AD would require accomplishment of the actions identified as “RC” (required for compliance) in the Accomplishment Instructions of the service information described previously, except for any differences identified as exceptions in the regulatory text of this proposed AD.
For information on the procedures and compliance times, see this service information at
This proposed AD would require the software installation specified in Boeing Alert Service Bulletin B787-81205-SB270039-00, Issue 002, dated March 8, 2018, prior to or concurrently with the tubing and valve installation on Model 787-9 airplanes. The effectivity in this service information applies to Model 787-8 and 787-9 airplanes; however, this proposed AD would only require those actions be accomplished on Model 787-9 airplanes.
We are considering additional rulemaking for Model 787-8 and 787-9 airplanes to require the software installation specified in Boeing Alert Service Bulletin B787-81205-SB270039-00, Issue 002, dated March 8, 2018, within a compliance time that may occur earlier than that for the tubing and valve installation specified in this proposed AD.
We estimate that this proposed AD affects 87 airplanes of U.S. registry. We estimate the following costs to comply with this proposed AD:
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This proposed AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes to the Director of the System Oversight Division.
We determined that this proposed AD would not have federalism implications under Executive Order 13132. This proposed AD would 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.
For the reasons discussed above, I certify this proposed regulation:
(1) Is not a “significant regulatory action” under Executive Order 12866,
(2) Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979),
(3) Will not affect intrastate aviation in Alaska, and
(4) Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA proposes to amend 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
We must receive comments by October 15, 2018.
None.
This AD applies to The Boeing Company airplanes, certificated in any category, as identified in paragraphs (c)(1) and (c)(2) of this AD.
(1) Model 787-8 airplanes identified in Boeing Alert Service Bulletin B787-81205-SB290032-00, Issue 001, dated November 17, 2017.
(2) Model 787-9 airplanes identified in Boeing Alert Service Bulletin B787-81205-SB290033-00, Issue 001, dated November 17, 2017.
Air Transport Association (ATA) of America Code 29, Hydraulic Power.
This AD was prompted by a determination that certain areas in the tire/wheel threat zones could be susceptible to damage, which could result in loss of braking on one main landing gear (MLG) truck, loss of nose wheel steering, and loss of directional control on the ground when below rudder effectiveness speed. We are issuing this AD to address damage from a MLG thrown tire tread or tire burst event, which could result in loss of directional control on the ground and consequent runway excursion.
Comply with this AD within the compliance times specified, unless already done.
(1) At the applicable time specified in paragraph 5, “Compliance,” of Boeing Alert Service Bulletin B787-81205-SB290032-00, Issue 001, dated November 17, 2017 (for Model 787-8 airplanes); or Boeing Alert Service Bulletin B787-81205-SB290033-00, Issue 001, dated November 17, 2017 (for Model 787-9 airplanes); as applicable; except as specified in paragraph (i) of this AD: Do all applicable actions identified as “RC” (required for compliance) in, and in accordance with, the Accomplishment Instructions of Boeing Alert Service Bulletin B787-81205-SB290032-00, Issue 001, dated November 17, 2017; or Boeing Alert Service Bulletin B787-81205-SB290033-00, Issue 001, dated November 17, 2017, as applicable.
(2) For Model 787-9 airplanes: Prior to or concurrently with accomplishing the actions required by paragraph (g)(1) of this AD, do all applicable actions (including software installation) identified as RC, in accordance with the Accomplishment Instructions of Boeing Alert Service Bulletin B787-81205-SB270039-00, Issue 002, dated March 8, 2018.
This paragraph provides credit for the actions specified in paragraph (g)(2) of this AD, if those actions were performed before the effective date of this AD using Boeing Alert Service Bulletin B787-81205-SB270039-00, Issue 001, dated July 31, 2017.
For purposes of determining compliance with the requirements of this AD: Where the service information identified in paragraph (g)(1) of this AD uses the phrase “the Issue 001 date on this service bulletin,” this AD requires using “the effective date of this AD.”
(1) The Manager, Seattle ACO Branch, FAA, has the authority to approve AMOCs for this AD, if requested using the procedures found in 14 CFR 39.19. In accordance with 14 CFR 39.19, send your request to your principal inspector or local Flight Standards District Office, as appropriate. If sending information directly to the manager of the certification office, send it to the attention of the person identified in paragraph (k)(1) of this AD. Information may be emailed to:
(2) Before using any approved AMOC, notify your appropriate principal inspector, or lacking a principal inspector, the manager of the local flight standards district office/certificate holding district office.
(3) An AMOC that provides an acceptable level of safety may be used for any repair, modification, or alteration required by this AD if it is approved by the Boeing Commercial Airplanes Organization Designation Authorization (ODA) that has been authorized by the Manager, Seattle ACO Branch, FAA, to make those findings. To be approved, the repair method, modification deviation, or alteration deviation must meet the certification basis of the airplane, and the approval must specifically refer to this AD.
(4) For service information that contains steps that are labeled as RC, the provisions of paragraphs (j)(4)(i) and (j)(4)(ii) of this AD apply.
(i) The steps labeled as RC, including substeps under an RC step and any figures identified in an RC step, must be done to comply with the AD. If a step or substep is labeled “RC Exempt,” then the RC requirement is removed from that step or substep. An AMOC is required for any deviations to RC steps, including substeps and identified figures.
(ii) Steps not labeled as RC may be deviated from using accepted methods in accordance with the operator's maintenance or inspection program without obtaining approval of an AMOC, provided the RC steps, including substeps and identified figures, can still be done as specified, and the airplane can be put back in an airworthy condition.
(1) For more information about this AD, contact Kelly McGuckin, Aerospace Engineer, Systems and Equipment Section, FAA, Seattle ACO Branch, 2200 South 216th St., Des Moines, WA 98198; phone and fax: 206-231-3546; email:
(2) For service information identified in this AD, contact Boeing Commercial Airplanes, Attention: Contractual & Data Services (C&DS), 2600 Westminster Blvd., MC 110-SK57, Seal Beach, CA 90740-5600; telephone 562-797-1717; internet
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
We propose to adopt a new airworthiness directive (AD) for certain Airbus SAS Model A330-200, -200F, and -300 series airplanes. This proposed AD was prompted by a revision of the airworthiness limitations section (ALS), which provides new and more restrictive maintenance requirements and airworthiness limitations for airplane structures and systems. This proposed AD would require revising the maintenance or inspection program to incorporate new maintenance requirements and airworthiness limitations. We are proposing this AD to address the unsafe condition on these products.
We must receive comments on this proposed AD by October 15, 2018.
You may send comments, using the procedures found in 14 CFR 11.43 and 11.45, by any of the following methods:
•
•
•
•
For service information identified in this NPRM, contact Airbus SAS, Airworthiness Office—EAL, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; phone: +33 5 61 93 36 96; fax: +33 5 61 93 45 80; email:
You may examine the AD docket on the internet at
Vladimir Ulyanov, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; phone and fax: 206-231-3229.
We invite you to send any written relevant data, views, or arguments about this proposal. Send your comments to an address listed under the
We will post all comments we receive, without change, to
The European Aviation Safety Agency (EASA), which is the Technical Agent for the Member States of the European Union, has issued EASA AD 2017-0228, dated November 21, 2017 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for all Airbus SAS Model A330 and A340 series airplanes. The MCAI states:
The airworthiness limitations are currently defined and published in the Airbus A330 and A340 Airworthiness Limitations Section (ALS) documents. The airworthiness limitations applicable to the System Equipment Maintenance Requirements, which are approved by EASA, are specified in Airbus A330 and A340 ALS Part 4. Failure to comply with these instructions could result in an unsafe condition.
EASA issued AD 2016-0011 [which corresponds to FAA AD 2017-05-10, Amendment 39-18821 (82 FR 13379, March 13, 2017) (“AD 2017-05-10”)] to require the actions as specified in Airbus A330 and A340 ALS Part 4 at Revision 05 and Revision 04, respectively.
Since this [EASA] AD was issued, Airbus published Revision 06 and Revision 05, respectively, of Airbus A330 and A340 ALS Part 4, which introduce new and more restrictive maintenance requirements and/or airworthiness limitations.
For the reason described above, this [EASA] AD retains the requirements of EASA AD 2016-0011, which is superseded, and requires accomplishment of the actions specified in Airbus A330 ALS Part 4 Revision 06, or A340 ALS Part 4 Revision 05, as applicable.
The unsafe condition is reduced control of the airplane due to the failure of system components.
You may examine the MCAI in the AD docket on the internet at
This NPRM would not propose to supersede AD 2017-05-10. Rather, we have determined that a stand-alone AD would be more appropriate to address the changes in the MCAI. This NPRM would require revising the maintenance or inspection program to incorporate new maintenance requirements and airworthiness limitations. Accomplishment of the proposed actions would then terminate all of the requirements of AD 2017-05-10.
Airbus SAS has issued A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017. This service information describes preventative maintenance requirements and associated airworthiness limitations applicable to aircraft systems susceptible to aging effects. This service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
This product has been approved by the aviation authority of another country, and is approved for operation in the United States. Pursuant to our bilateral agreement with the State of Design Authority, we have been notified of the unsafe condition described in the MCAI and service information referenced above. We are proposing this AD because we evaluated all the relevant information and determined the unsafe condition described previously is likely to exist or develop on other products of the same type design.
This proposed AD would require revising the maintenance or inspection program to incorporate new maintenance requirements and airworthiness limitations.
EASA AD 2017-0228, dated November 21, 2017, specifies that if there are findings from the ALS inspection tasks, corrective actions must be accomplished in accordance with Airbus SAS maintenance documentation. However, this proposed AD does not include that requirement. Operators of U.S.-registered airplanes are required by general airworthiness and operational regulations to perform maintenance using methods that are acceptable to the FAA. We consider those methods to be adequate to address any corrective actions necessitated by the findings of ALS inspections required by this proposed AD.
This proposed AD does not include Model A340 series airplanes in the Applicability. AD 2014-23-17, Amendment 39-18033 (79 FR 71304, December 2, 2014), currently addresses the identified unsafe condition for Model A340 series airplanes. We have also added EASA AD 2017-0228, dated November 21, 2017, to the required airworthiness action list (RAAL) for Model A340 series airplanes.
The FAA recently became aware of an issue related to the applicability of ADs that require incorporation of an ALS
Typically, when these types of ADs are issued by civil aviation authorities of other countries, they apply to all airplanes covered under an identified type certificate (TC). The corresponding FAA AD typically retains applicability to all of those airplanes.
In addition, U.S. operators must operate their airplanes in an airworthy condition, in accordance with 14 CFR 91.7(a). Included in this obligation is the requirement to perform any maintenance or inspections specified in the ALS, and in accordance with the ALS as specified in 14 CFR 43.16 and 91.403(c), unless an alternative has been approved by the FAA.
When a TC is issued for a type design, the specific ALS, including revisions, is a part of that type design, as specified in 14 CFR 21.31(c).
The sum effect of these operational and maintenance requirements is an obligation to comply with the ALS defined in the type design referenced in the manufacturer's conformity statement. This obligation may introduce a conflict with an AD that requires a specific ALS revision if new airplanes are delivered with a later revision as part of their type design.
To address this conflict, the FAA has approved alternative methods of compliance (AMOCs) that allow operators to incorporate the most recent ALS revision into their maintenance/inspection programs, in lieu of the ALS revision required by the AD. This eliminates the conflict and enables the operator to comply with both the AD and the type design.
However, compliance with AMOCs is normally optional, and we recently became aware that some operators choose to retain the AD-mandated ALS revision in their fleet-wide maintenance/inspection programs, including those for new airplanes delivered with later ALS revisions, to help standardize the maintenance of the fleet. To ensure that operators comply with the applicable ALS revision for newly delivered airplanes containing a later revision than that specified in an AD, we plan to limit the applicability of ADs that mandate ALS revisions to those airplanes that are subject to an earlier revision of the ALS, either as part of the type design or as mandated by an earlier AD.
This proposed AD therefore would apply to Airbus SAS airplanes identified in paragraph (c) of this proposed AD with an original certificate of airworthiness or original export certificate of airworthiness that was issued on or before the date of the ALS revision identified in this proposed AD. Operators of airplanes with an original certificate of airworthiness or original export certificate of airworthiness issued after that date must comply with the airworthiness limitations specified as part of the approved type design and referenced on the TC data sheet.
We estimate that this proposed AD affects 104 airplanes of U.S. registry.
We have determined that revising the maintenance or inspection program takes an average of 90 work-hours per operator, although we recognize that this number may vary from operator to operator. In the past, we have estimated that this action takes 1 work-hour per airplane. Since operators incorporate maintenance or inspection program changes for their affected fleet(s), we have determined that a per-operator estimate is more accurate than a per-airplane estimate. Therefore, we estimate the total cost per operator to be $7,650 (90 work-hours × $85 per work-hour).
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This proposed AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes to the Director of the System Oversight Division.
We determined that this proposed AD would not have federalism implications under Executive Order 13132. This proposed AD would 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.
For the reasons discussed above, I certify this proposed regulation:
1. Is not a “significant regulatory action” under Executive Order 12866;
2. Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979);
3. Will not affect intrastate aviation in Alaska; and
4. Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA proposes to amend 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
We must receive comments by October 15, 2018.
This AD affects AD 2017-05-10, Amendment 39-18821 (82 FR 13379, March 13, 2017) (“AD 2017-05-10”).
This AD applies to Airbus SAS Model A330-201, A330-202, A330-203, A330-223, A330-243, A330-223F, A330-243F, A330-301, A330-302, A330-303, A330-321, A330-322, A330-323, A330-341, A330-342, and A330-343 airplanes, certificated in any category, with an original certificate of airworthiness or original export certificate of airworthiness issued on or before September 18, 2017.
Air Transport Association (ATA) of America Code 05, Time Limits/Maintenance Checks.
This AD was prompted by a revision of the airworthiness limitations section (ALS), which provides new and more restrictive maintenance requirements and airworthiness limitations for airplane structures and systems. We are issuing this AD to prevent reduced airplane control due to the failure of system components.
Comply with this AD within the compliance times specified, unless already done.
Within 90 days after the effective date of this AD, revise the maintenance or inspection program, as applicable, by incorporating Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017. The initial compliance times for the actions specified in Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, are within the applicable compliance times specified in Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, or within 90 days after the effective date of this AD, whichever occurs later, except as required by paragraph (h) of this AD.
(1) Where Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, defines a calendar compliance time for elevator servo-controls having part number (P/N) SC4800-2, SC4800-3, SC4800-4, SC4800-6, SC4800-7, or SC4800-8 as “August 31, 2004,” the calendar compliance time is June 13, 2007 (34 months after August 13, 2004 (the effective date of AD 2004-13-25, Amendment 39-13707 (69 FR 41394, July 9, 2004))).
(2) Where Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, defines a calendar compliance time for spoiler servo-controls (SSCs) having P/N 1386A0000-01, 1386B0000-01, 1387A0000-01, or 1387B0000-01 as “December 31, 2003,” the calendar compliance time is November 19, 2005 (13 months after October 19, 2004 (the effective date of AD 2004-18-14, Amendment 39-13793 (69 FR 55326, September 14, 2004))).
(3) Where Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, defines a calendar compliance time for elevator servo-controls having P/N SC4800-73, SC4800-93, SC4800-103, and SC4800-113 as “June 30, 2008,” the calendar compliance time is September 16, 2009 (17 months after April 16, 2008 (the effective date of AD 2008-06-07, Amendment 39-15419 (73 FR 13103, March 12, 2008; corrected April 15, 2008 (73 FR 20367)))).
(4) The initial compliance time for replacement of the retraction brackets of the main landing gear (MLG) having a part number specified in paragraphs (h)(4)(i) through (h)(4)(xvi) of this AD is before the accumulation of 19,800 total landings on the affected retraction brackets of the MLG, or within 900 flight hours after April 9, 2012 (the effective date of AD 2012-04-07, Amendment 39-16963 (77 FR 12989, March 5, 2012)), whichever occurs later.
(i) 201478303.
(ii) 201478304.
(iii) 201478305.
(iv) 201478306.
(v) 201478307.
(vi) 201478308.
(vii) 201428380.
(viii) 201428381.
(ix) 201428382.
(x) 201428383.
(xi) 201428384.
(xii) 201428385.
(xiii) 201428378.
(xiv) 201428379.
(xv) 201428351.
(xvi) 201428352.
(5) Where Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, defines a calendar compliance time for the modification of SSCs on three hydraulic circuits having P/N MZ4339390-01X, MZ4306000-01X, MZ4339390-02X, MZ4306000-02X, MZ4339390-10X, or MZ4306000-10X as “March 5, 2010,” the calendar compliance time is April 14, 2011 (18 months after October 14, 2009 (the effective date of AD 2009-18-20, Amendment 39-16017 (74 FR 46313, September 9, 2009) (“AD 2009-18-20”))).
(6) Where Note (17) of Sub-Part 1, “Life Limits,” of Section 3, “Systems Life-Limited Components,” of Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, defines a calendar date of “September 5, 2008,” as a date for the determination of accumulated flight cycles since the airplane's initial entry into service, the date is October 14, 2009 (the effective date of AD 2009-18-20).
(7) Where Note (17) of Sub-Part 1, “Life Limits,” of Section 3, “Systems Life-Limited Components,” of Airbus A330 Airworthiness Limitations Section (ALS) Part 4, System Equipment Maintenance Requirements (SEMR), Revision 06, dated September 18, 2017, defines a calendar compliance time as “March 5, 2010,” for the modification of affected servo controls, the calendar compliance time is April 14, 2011 (18 months after October 14, 2009 (the effective date of AD 2009-18-20)).
After accomplishing the revision required by paragraph (g) of this AD, no alternative actions (
Accomplishing the actions required by paragraph (g) of this AD terminates all requirements of AD 2017-05-10.
The following provisions also apply to this AD:
(1)
(2)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA AD 2017-0228, dated November 21, 2017, for related information. This MCAI may be found in the AD docket on the internet at
(2) For more information about this AD, contact Vladimir Ulyanov, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; phone and fax: 206-231-3229.
(3) For service information identified in this AD, contact Airbus SAS, Airworthiness Office—EAL, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; phone: +33 5 61 93 36 96; fax: +33 5 61 93 45 80; email:
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
We propose to adopt a new airworthiness directive (AD) for all Airbus SAS Model A330-200 Freighter series airplanes, Model A330-200 and -300 series airplanes, and Model A340-200 and -300 series airplanes. This proposed AD was prompted by defects found during production tests of ram air turbine (RAT) units; investigation revealed that the defects were due to certain RAT hydraulic pumps having an alternative manufacturing process of the pump pistons. This proposed AD would require replacing any defective RAT hydraulic pump with a serviceable part and re-identifying the RAT module part number. We are proposing this AD to address the unsafe condition on these products.
We must receive comments on this proposed AD by October 15, 2018.
You may send comments, using the procedures found in 14 CFR 11.43 and 11.45, by any of the following methods:
•
•
•
•
For service information identified in this NPRM, contact Airbus SAS, Airworthiness Office—EIAS, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
You may examine the AD docket on the internet at
Vladimir Ulyanov, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax: 206-231-3229.
We invite you to send any written relevant data, views, or arguments about this proposal. Send your comments to an address listed under the
We will post all comments we receive, without change, to
The European Aviation Safety Agency (EASA), which is the Technical Agent for the Member States of the European Union, has issued EASA AD 2018-0062, dated March 20, 2018 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for all Airbus SAS Model A330-200 Freighter series airplanes, Model A330-200 and -300 series airplanes, and Model A340-200 and -300 series airplanes. The MCAI states:
Four A330 RAT units were returned to the supplier due to low discharge pressure. These defects were detected during Airbus production tests. Subsequent investigations by the RAT manufacturer UTAS (formerly Hamilton Sundstrand) revealed that some RAT hydraulic pumps, [part number] P/N 5916430, were involved in an alternative manufacturing process of the pump pistons. This resulted in form deviations (rough surface finish and sharp edges), which caused excessive wear and damage to the bore where the pistons moved.
This condition, if not corrected, could lead to low performance of the pump, possibly resulting in reduced control of the aeroplane, particularly if occurring following a total engine flame out, or during a total loss of normal electrical power generation.
To address this potential unsafe condition, Airbus published [service bulletin] SB A330-29-3130 and SB A340-29-4098, providing instructions for identification and replacement of the affected parts.
For the reasons described above, this [EASA] AD requires replacement of the affected parts. This [EASA] AD also requires re-identification of the RAT module.
You may examine the MCAI in the AD docket on the internet at
The FAA issued AD 2016-14-01, Amendment 39-18582 (81 FR 44983, July 12, 2016); corrected (81 FR 51097, August 3, 2016) (“AD 2016-14-01”). AD 2016-14-01 applies to certain Airbus SAS Model A330-200 Freighter series airplanes; Model A330-200 and A330-300 series airplanes; Model A340-200 and A340-300 series airplanes; Model A340-500 series airplanes; and Model A340-600 series airplanes. AD 2016-14-01 requires identification of the manufacturer, part number, and serial number of the RAT, and re-identification and modification of the RAT if necessary. AD 2016-14-01 was prompted by a report indicating that, during an operational test of a RAT, the RAT did not deploy in automatic mode. AD 2016-14-01 was issued to prevent non-deployment of the RAT, which, following a total engine flame-out, or during a total loss of normal electrical power generation, could result in reduced control of the airplane.
Airbus SAS has issued Service Bulletins A330-29-3130 and A340-29-4098, both dated May 3, 2017. This service information describes procedures for replacing any affected RAT hydraulic pump with a serviceable
UTC Aerospace Systems has issued Service Bulletin ERPS06M-29-22, dated March 17, 2017, and Revision 1, dated June 27, 2017. This service information identifies affected part and serial numbers for the RAT hydraulic pump. These documents are distinct since UTC Aerospace Systems Service Bulletin ERPS06M-29-22, Revision 1, dated June 27, 2017, adds a Parker part number reference to each Hamilton Sundstrand hydraulic part number.
This service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
This product has been approved by the aviation authority of another country, and is approved for operation in the United States. Pursuant to our bilateral agreement with the State of Design Authority, we have been notified of the unsafe condition described in the MCAI and service information referenced above. We are proposing this AD because we evaluated all the relevant information and determined the unsafe condition described previously is likely to exist or develop on other products of the same type design.
This proposed AD would require accomplishing the actions specified in the service information described previously.
We estimate that this proposed AD affects 103 airplanes of U.S. registry. We estimate the following costs to comply with this proposed AD:
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This proposed AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes to the Director of the System Oversight Division.
We determined that this proposed AD would not have federalism implications under Executive Order 13132. This proposed AD would 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.
For the reasons discussed above, I certify this proposed regulation:
1. Is not a “significant regulatory action” under Executive Order 12866;
2. Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979);
3. Will not affect intrastate aviation in Alaska; and
4. Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA proposes to amend 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
We must receive comments by October 15, 2018.
This AD affects AD 2016-14-01, Amendment 39-18582 (81 FR 44983, July 12, 2016); corrected (81 FR 51097, August 3, 2016) (“AD 2016-14-01”).
This AD applies to the airplanes identified in paragraphs (c)(1), (c)(2), (c)(3), (c)(4), and (c)(5) of this AD, certificated in any category, all manufacturer serial numbers.
(1) Airbus SAS Model A330-223F and -243F airplanes.
(2) Airbus SAS Model A330-201, -202, -203, -223, and -243 airplanes.
(3) Airbus SAS Model A330-301, -302, -303, -321, -322, -323, -341, -342, and -343 airplanes.
(4) Airbus SAS Model A340-211, -212, -213 airplanes.
(5) Airbus SAS Model A340-311, -312, and -313 airplanes.
Air Transport Association (ATA) of America Code 29, Hydraulic Power.
This AD was prompted by defects found during production tests of ram air turbine (RAT) units; investigation revealed that the defects were due to certain RAT hydraulic pumps having an alternative manufacturing process of the pump pistons. We are issuing this AD to prevent low performance of the pump, which, following a total engine flame-out, or during a total loss of normal electrical power generation, could result in reduced control of the airplane.
Comply with this AD within the compliance times specified, unless already done.
(1) An affected part is a RAT hydraulic pump having part number (P/N) 5916430 and a serial number identified in UTC Aerospace Systems Service Bulletin ERPS06M-29-22, dated March 17, 2017, or Revision 1, dated June 27, 2017.
(2) A serviceable part is a RAT hydraulic pump identified as acceptable in Airbus Service Bulletin A330-29-3130 or A340-29-4098, both dated May 3, 2017, as applicable.
(3) Group 1 airplanes are airplanes on which an affected part is installed.
(4) Group 2 airplanes are airplanes on which no affected part is installed. A Model A330 airplane on which Airbus SAS Modification 206604 has been embodied in production is a Group 2 airplane, provided that the airplane remains in that configuration.
(1) Within 18 months after the effective date of this AD; replace any affected RAT hydraulic pump with a serviceable part, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A330-29-3130 or A340-29-4098, both dated May 3, 2017, as applicable.
(2) Concurrently with the replacement required by paragraph (h)(1) of this AD, re-identify the part number of the serviceable RAT module, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A330-29-3130 or A340-29-4098, both dated May 3, 2017, as applicable.
Note 1 to paragraph (h)(2) of this AD: Airbus Service Bulletins A330-29-3130 and A340-29-4098, both dated May 3, 2017, provide guidance for re-identification of the part numbers of the RAT hydraulic pumps that are not affected, and the part numbers of the RAT modules that are not equipped with an affected hydraulic pump.
After re-identification of a RAT module on an airplane, as required by paragraph (h)(2) of this AD, the airplane remains compliant with the RAT module re-identification requirements of AD 2016-14-01 for that airplane.
(1) For Group 1 airplanes: After replacement of any affected RAT hydraulic pump as required by paragraph (h)(1) of this AD, do not install any affected RAT hydraulic pump.
(2) For Group 2 airplanes: As of the effective date of this AD, do not install any affected RAT hydraulic pump.
The following provisions also apply to this AD:
(1)
(2)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA AD 2018-0062, dated March 20, 2018, for related information. This MCAI may be found in the AD docket on the internet at
(2) For more information about this AD, contact Vladimir Ulyanov, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax: 206-231-3229.
(3) For service information identified in this AD, contact Airbus SAS, Airworthiness Office—EIAS, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
We propose to supersede Airworthiness Directive (AD) 2016-07-23, which applies to all Airbus SAS Model A318, A319, A320, and A321 series airplanes. AD 2016-07-23 requires, for certain airplanes, repetitive replacements of the fixed fairing upper and lower attachment studs of both the left-hand (LH) and right-hand (RH) main landing gear (MLG); and repetitive inspections for corrosion, wear, fatigue cracking, and loose studs of each forward stud assembly of the fixed fairing door upper and lower forward attachments of both the LH and RH MLG; and replacement if necessary. AD 2016-07-23 also provides an optional terminating modification for the repetitive replacements of the fixed fairing upper and lower attachment studs. Since we issued AD 2016-07-23, we have determined that for some airplane configurations, associated fixed fairing assembly part numbers susceptible to fatigue cracking were not listed in certain service information required by AD 2016-07-23. In addition, we have determined that additional work is necessary to re-identify the fixed fairing assembly part number on certain airplanes. This proposed AD would retain the requirements of AD 2016-07-23 and, for certain airplanes, require re-identification of the LH and RH fixed fairing assemblies' part numbers. We are proposing this AD to address the unsafe condition on these products.
We must receive comments on this proposed AD by October 15, 2018.
You may send comments, using the procedures found in 14 CFR 11.43 and 11.45, by any of the following methods:
•
•
•
•
For service information identified in this NPRM, contact Airbus SAS, Airworthiness Office—EIAS, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
You may examine the AD docket on the internet at
Sanjay Ralhan, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3223.
We invite you to send any written relevant data, views, or arguments about this proposal. Send your comments to an address listed under the
We will post all comments we receive, without change, to
We issued AD 2016-07-23, Amendment 39-18468 (81 FR 26115, May 2, 2016) (“AD 2016-07-23”), for all Airbus SAS Model A318, A319, A320, and A321 series airplanes. AD 2016-07-23 requires, for certain airplanes, repetitive replacements of the fixed fairing upper and lower attachment studs of both the LH and RH MLG; and repetitive inspections for corrosion, wear, fatigue cracking, and loose studs of each forward stud assembly of the fixed fairing door upper and lower forward attachment of both the LH and RH MLG; and replacement if necessary. AD 2016-07-23 also provides an optional terminating modification for the repetitive replacements of the fixed fairing upper and lower attachment studs. AD 2016-07-23 resulted from reports of in-flight loss of fixed and hinged MLG fairings, and reports of post-modification MLG fixed fairing assemblies that have wear and corrosion. We issued AD 2016-07-23 to address in-flight detachment of an MLG fixed fairing and consequent damage to the airplane.
Since we issued AD 2016-07-23, we have determined that for some airplane configurations, associated fixed fairing assembly part numbers susceptible to fatigue cracking were not listed in certain service information required by AD 2016-07-23. In addition, we have determined that additional work is necessary to re-identify the fixed fairing assembly part number after completion of the optional terminating modification. This proposed AD would retain the requirements of AD 2016-07-23 and require re-identification of the part number of the LH and RH fixed fairing assemblies after completion of the optional terminating modification.
The European Aviation Safety Agency (EASA), which is the Technical Agent for the Member States of the European Union, has issued EASA AD 2018-0023, dated January 26, 2018; corrected February 5, 2018 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for all Airbus SAS Model A318 and A319 series airplanes; all Airbus SAS Model A320-211, A320-212, A320-214, A320-216, A320-231, A320-232, and A320-233 airplanes; and all Airbus SAS Model A321-111, A321-112, A321-131, A321-211, A321-212, A321-213, A321-231 and A321-232 airplanes. The MCAI states:
Several occurrences were reported of in-flight loss of main landing gear (MLG) fixed and hinged fairings. The majority of reported events occurred following scheduled maintenance activities. One result of the investigation was that a discrepancy between the drawing and the maintenance manuals was discovered. The maintenance documents were corrected to prevent mis-rigging of the MLG fixed and hinged fairings, which could induce fatigue cracking.
Prompted by these findings, Airbus issued Service Bulletin (SB) A320-52-1083, providing instructions for a one-time inspection of the MLG fixed fairing composite insert and the surrounding area, replacement of the adjustment studs at the lower forward position and adjustment to the new clearance tolerances. That SB was replaced by Airbus SB A320-52-1100 (modification (mod) 27716) introducing a re-designed location stud, rod end and location plate at the forward upper and lower leg fixed-fairing positions. Subsequently, reports were received of post-mod 27716/post-SB A320-52-1100 MLG fixed fairing assemblies with corrosion, which could also induce cracking.
This condition, if not detected and corrected, could lead to further cases of in-flight detachment of a MLG fixed fairing, possibly resulting in injury to persons on the ground and/or damage to the aeroplane.
To address this potential unsafe condition, EASA issued AD 2014-0096 to require repetitive detailed inspections (DET) of the MLG fixed fairings, and, depending on findings, accomplishment of applicable corrective actions. That [EASA] AD also prohibited installation of certain MLG fixed fairing rod end assemblies and studs as replacement parts on aeroplanes incorporating Airbus mod 27716 in production, or modified in accordance with Airbus SB A320-52-1100 (any revision) in service.
Since EASA AD 2014-0096 was issued, Airbus developed an alternative inspection programme to meet the [EASA] AD requirements. In addition, a terminating action (mod 155648) was developed, which was made available for in-service aeroplanes through Airbus SB A320-52-1165.
Consequently, EASA issued AD 2015-0001 (later revised), retaining the requirements of EASA AD 2014-0096, which was superseded, and adding an optional terminating action for the repetitive inspections. For post-mod aeroplanes,
Since EASA AD 2015-0001R1 [which corresponds to FAA AD 2016-07-23] was issued, Airbus revised SB A320-52-1165 to include additional work, to re-identify the fairing assembly part number (P/N). During the preparation of this additional work, it was noted that several configurations and associated P/N were not listed in the original SB, which may have an impact on aeroplanes on which SB A320-52-1165 original issue or Revision (rev.) 01 was already accomplished. It has also been noticed that the instructions for reidentification of two P/N were not correct in revision 02 of this SB.
For the reasons described above, this [EASA] AD retains the requirement of EASA AD 2015-0001R1, which is superseded, but requires using the SB at rev. 03.
This [EASA] AD also requires accomplishment of additional work [re-identification of the part number for the LH and RH fixed fairing assemblies] for those aeroplanes on which parts were replaced in accordance with the instructions of Airbus SB A320-52-1165 at original issue, rev. 01 or rev. 02 and correct (re)identification as applicable.
You may examine the MCAI in the AD docket on the internet at
Airbus SAS has issued the following service information.
• Airbus Service Bulletin A320-52-1100, Revision 01, dated March 12, 1999. This service information describes procedures for modification of the airplane to post-Airbus Modification 27716 configuration (by replacing the location stud, rod end, and location plate at the forward upper and lower leg fixed-fairing positions of the MLG door assemblies). The modification includes a resonance frequency inspection for debonding of the composite insert and delamination of the honeycomb area around the insert, and applicable corrective actions. Corrective actions include repairing the insert. The actions in this service information are an optional terminating modification.
• Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015. This service information describes procedures for inspection of the fixed fairing door upper and lower forward attachments of the LH and RH MLG, and replacement of the fixed fairing upper and lower attachment studs of the LH and RH MLG.
• Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017. The service information describes procedures for replacing the fixed fairing attachment stud assemblies of the MLG door assembly with new assemblies, and re-identifying the part number of the LH and RH MLG fixed fairing assemblies. The actions in this service information are an optional terminating modification.
The service information is reasonably available because the interested parties have access to it through their normal course of business or by the means identified in the
This product has been approved by the aviation authority of another country, and is approved for operation in the United States. Pursuant to our bilateral agreement with the State of Design Authority, we have been notified of the unsafe condition described in the MCAI and service information referenced above. We are proposing this AD because we evaluated all pertinent information and determined an unsafe condition exists and is likely to exist or develop on other products of the same type design.
This proposed AD would retain all of the requirements of AD 2016-07-23. This proposed AD would require accomplishing the actions specified in the service information described previously.
We estimate that this proposed AD affects 901 airplanes of U.S. registry. We estimate the following costs to comply with this proposed AD:
We estimate the following costs to do any necessary replacements or re-identifications that would be required based on the results of the inspection. We have no way of determining the number of aircraft that might need these replacements or re-identifications:
According to the manufacturer, some or all of the costs of this AD may be covered under warranty, thereby reducing the cost impact on affected individuals. We do not control warranty coverage for affected individuals. As a result, we have included all costs in our cost estimate.
Title 49 of the United States Code specifies the FAA's authority to issue rules on aviation safety. 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.
We are issuing this rulemaking under the authority described in Subtitle VII, Part A, Subpart III, Section 44701: “General requirements.” Under that section, Congress charges the FAA with promoting safe flight of civil aircraft in air commerce by prescribing regulations for practices, methods, and procedures the Administrator finds necessary for safety in air commerce. This regulation is within the scope of that authority because it addresses an unsafe condition that is likely to exist or develop on products identified in this rulemaking action.
This proposed AD is issued in accordance with authority delegated by the Executive Director, Aircraft Certification Service, as authorized by FAA Order 8000.51C. In accordance with that order, issuance of ADs is normally a function of the Compliance and Airworthiness Division, but during this transition period, the Executive Director has delegated the authority to issue ADs applicable to transport category airplanes to the Director of the System Oversight Division.
We determined that this proposed AD would not have federalism implications under Executive Order 13132. This proposed AD would 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.
For the reasons discussed above, I certify this proposed regulation:
1. Is not a “significant regulatory action” under Executive Order 12866,
2. Is not a “significant rule” under the DOT Regulatory Policies and Procedures (44 FR 11034, February 26, 1979),
3. Will not affect intrastate aviation in Alaska, and
4. Will not have a significant economic impact, positive or negative, on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
Air transportation, Aircraft, Aviation safety, Incorporation by reference, Safety.
Accordingly, under the authority delegated to me by the Administrator, the FAA proposes to amend 14 CFR part 39 as follows:
49 U.S.C. 106(g), 40113, 44701.
We must receive comments by October 15, 2018.
This AD replaces AD 2016-07-23, Amendment 39-18468 (81 FR 26115, May 2, 2016) (“AD 2016-07-23”).
This AD applies to the Airbus SAS airplanes identified in paragraphs (c)(1) through (c)(4) of this AD, certificated in any category, all manufacturer serial numbers.
(1) Model A318-111, A318-112, A318-121, and A318-122 airplanes.
(2) Model A319-111, A319-112, A319-113, A319-114, A319-115, A319-131, A319-132, and A319-133 airplanes.
(3) Model A320-211, A320-212, A320-214, A320-216, A320-231, A320-232, and A320-233 airplanes.
(4) Model A321-111, A321-112, A321-131, A321-211, A321-212, A321-213, A321-231 and A321-232 airplanes.
Air Transport Association (ATA) of America Code 52, Doors.
This AD was prompted by reports of in-flight loss of fixed and hinged main landing gear (MLG) fairings, and reports of post-modification MLG fixed fairing assemblies that have wear and corrosion. This AD was also prompted by a determination that for some airplane configurations, associated fixed fairing assembly part numbers susceptible to fatigue cracking were not listed in certain service information required by AD 2016-07-23. In addition, we have determined that additional work is necessary to re-identify the fixed fairing assembly part number on certain airplanes. We are issuing this AD to prevent in-flight detachment of an MLG fixed fairing and consequent damage to the airplane.
Comply with this AD within the compliance times specified, unless already done.
This paragraph restates the requirements of paragraph (g) of AD 2016-07-23, with no changes. For airplanes in pre-Airbus Modification 27716 and pre-Airbus Service Bulletin A320-52-1100 configuration, with any of the components installed that are identified in paragraphs (g)(1) through (g)(5) of this AD: At the applicable compliance time specified in paragraph (h) of this AD, replace fixed fairing upper and lower attachment studs of both left-hand (LH) and right-hand (RH) MLG, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015. Repeat the replacements thereafter at intervals not to exceed 6,500 flight cycles.
(1) Plate—support having part number (P/N) D5284024820000.
(2) Plate—support having P/N D5284024820200.
(3) Stud—adjustment having P/N D5284024420000.
(4) Rod end assembly (lower) having P/N D5284000500000.
(5) Rod end assembly (upper) having P/N D5284000600000.
This paragraph restates the requirements of paragraph (h) of AD 2016-07-23, with no changes. For airplanes identified in paragraph (g) of this AD, except as provided by paragraph (o) of this AD: Do the initial replacement required by paragraph (g) of this AD at the latest of the times specified in paragraphs (h)(1) through (h)(4) of this AD.
(1) Before the accumulation of 6,500 total flight cycles since the airplane's first flight.
(2) Within 6,500 flight cycles since the last installation of a pre-Airbus Modification 27716 stud on the airplane.
(3) Within 1,500 flight cycles after June 6, 2016 (the effective date of AD 2016-07-23).
(4) Within 8 months after June 6, 2016 (the effective date of AD 2016-07-23).
This paragraph restates the requirements of paragraph (i) of AD 2016-07-23, with no changes. For airplanes in post-Airbus Modification 27716 or post-Airbus Service Bulletin A320-52-1100 configuration, with any of the components installed that are identified in paragraphs (i)(1), (i)(2), and (i)(3) of this AD: At the applicable compliance time specified in paragraph (j) of this AD, do a detailed inspection of the LH and RH MLG forward stud assemblies of the fixed fairing door upper and lower forward attachments of both LH and RH MLG for indications of corrosion, wear, fatigue cracking, and loose studs, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015. Repeat the detailed inspection thereafter at intervals not to exceed 12 months. Replacement of both LH and RH MLG forward stud assemblies on an airplane, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015, extends the interval for the next detailed inspection to 72 months; and the inspection must be repeated thereafter at intervals not to exceed 12 months.
(1) Stud—adjustment having P/N D5285600720000.
(2) Rod end assembly (lower) having P/N D5285600400000.
(3) Rod end assembly (upper) having P/N D5285600500000.
This paragraph restates the requirements of paragraph (j) of AD 2016-07-23, with no changes. For airplanes identified in paragraph (i) of this AD, except as provided by paragraph (o) of this AD: Do the initial inspection required by paragraph (i) of this AD at the latest of the times specified in paragraphs (j)(1) through (j)(4) of this AD.
(1) Before the accumulation of 72 months since the airplane's first flight.
(2) Within 72 months since the last installation of a post-Airbus Modification 27716 assembly or since accomplishment of the actions specified in Airbus Service Bulletin A320-52-1100.
(3) Within 1,500 flight cycles after June 6, 2016 (the effective date of AD 2016-07-23).
(4) Within 8 months after June 6, 2016 (the effective date of AD 2016-07-23).
This paragraph restates the requirements of paragraph (k) of AD 2016-07-23, with revised service information. If any discrepancy (including any indication of corrosion, wear, fatigue cracking, or loose studs) of any MLG forward stud assembly is found during any inspection required by paragraph (i) of this AD, except as specified in paragraph (l) of this AD: Before further flight, replace the discrepant upper and lower fixed fairing forward stud assemblies of the LH and RH MLG, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015; or Airbus Service Bulletin A320-52-1165, Revision 01, dated October 23, 2015, excluding Appendix 01, dated November 3, 2014, and including Appendix 02, dated October 23, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017. As of the effective date of this AD only Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, may be used.
This paragraph restates the requirements of paragraph (l) of AD 2016-07-23, with revised service information. If any corrosion is found during any inspection required by paragraph (i) of this AD on any MLG fixed fairing forward stud assembly (upper, lower, LH or RH), but the corroded stud is not loose: Do the action specified in paragraph (l)(1) or (l)(2) of this AD.
(1) Before further flight, replace the affected assembly, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015; or Airbus Service Bulletin A320-52-1165, Revision 01, dated October 23, 2015, excluding Appendix 01, dated November 3, 2014, and including Appendix 02, dated October 23, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017. As of the effective date of this AD only Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, may be used.
(2) Within 4 months after finding corrosion, and thereafter at intervals not to exceed 4 months, do a detailed inspection for indications of corrosion, wear, fatigue cracking, and loose studs of the forward stud assembly of the affected (LH or RH) MLG, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015.
This paragraph restates the requirements of paragraph (m) of AD 2016-07-23, with revised service information. If any indication of wear, fatigue cracking, or loose studs of any forward stud assembly is found during any inspection required by paragraph (l)(2) of this AD: Before further flight, replace the affected (LH or RH) MLG fixed fairing forward stud assembly, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015; or Airbus Service Bulletin A320-52-1165, Revision 01, dated October 23, 2015, excluding Appendix 01, dated November 3, 2014, and including Appendix 02, dated October 23, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017. As of the effective date of this AD only Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, may be used.
This paragraph restates the requirements of paragraph (n) of AD 2016-07-23, with revised service information.
(1) Replacement of parts on an airplane, as required by paragraph (g), (k), (l)(1), or (m) of this AD, does not constitute terminating action for the repetitive inspections required by paragraph (i) of this AD, except as specified in paragraph (n)(3) of this AD.
(2) The repetitive replacements required by paragraph (g) of this AD may be terminated by modification of the airplane to post-Airbus Modification 27716 configuration, including a resonance frequency inspection for debonding of the composite insert and delamination of the honeycomb area around the insert, and all applicable corrective actions, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1100, Revision 01, dated March 12, 1999, provided all applicable corrective actions are done before further flight. Thereafter, refer to paragraph (i) of this AD to determine the compliance time for the next detailed inspection required by this AD.
(3) Modification of an airplane, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1165, Revision 01, dated October 23, 2015, excluding Appendix 01, dated November 3, 2014, and including Appendix 02, dated October 23, 2015; or Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, constitutes terminating action for actions required by paragraphs (g) through (m) of this AD for the airplane on which the modification is done. As of the effective date of this AD only Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, may be used.
This paragraph restates the requirements of paragraph (o) of AD 2016-07-23, with no changes. An airplane on which Airbus Modification 155648 has been embodied in production is not affected by the requirements of paragraphs (g) and (i) of this AD, provided that no affected component, identified by part number as specified in paragraphs (g)(1) through (g)(5) and (i)(1) through (i)(3) of this AD, has been installed on that airplane since first flight of the airplane.
This paragraph restates the requirements of paragraph (p) of AD 2016-07-23, with no changes.
(1) For airplanes in pre-Airbus Modification 27716 or pre-Airbus Service Bulletin A320-52-1100 configuration: No person may install a component identified in paragraphs (g)(1) through (g)(5) of this AD on any airplane after doing the actions provided in paragraph (n)(2) of this AD.
(2) For airplanes in post-Airbus Modification 27716 or post Airbus Service Bulletin A320-52-1100 configuration: As of the effective date of this AD, no person may install a component identified in paragraphs (g)(1) through (g)(5) of this AD on any airplane.
(3) For airplanes in pre-Airbus Modification 155648 or pre-Airbus Service Bulletin A320-52-1165 configuration: No person may install a component identified in paragraphs (g)(1) through (g)(5) and (i)(1) through (i)(3) of this AD on any airplane after doing the actions provided in paragraph (n)(3) of this AD.
(4) For airplanes in post-Airbus Modification 155648 or post-Airbus Service Bulletin A320-52-1165 configuration: As of the effective date of this AD, no person may install a component identified in (g)(1) through (g)(5) and (i)(1) through (i)(3) of this AD on any airplane.
This paragraph restates the requirements of paragraph (q) of AD 2016-07-23, with no changes. Although Airbus Service Bulletin A320-52-1163, Revision 01, including Appendix 01, dated June 22, 2015, specifies to submit certain information to the manufacturer, and specifies that action as “RC” (Required for Compliance), this AD does not include that requirement.
For any airplane on which, before the effective date of this AD, any part was installed or replaced, in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1165, dated November 3, 2014; Revision 01, dated October 13, 2015; or Revision 02, dated February 12, 2016: Within 12 months after the effective date of this AD, accomplish the instructions identified as “additional work” in the Accomplishment Instructions of Airbus Service Bulletin A320-52-1165,
Modification of an airplane in accordance with the Accomplishment Instructions of Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, or as specified in paragraph (r) of this AD constitutes terminating action for the requirements of paragraphs (g), (i), (k), (l), and (m) of this AD for that airplane.
(1) Do not install on any airplane a component specified in paragraphs (g)(1) through (g)(5) of this AD, as required by paragraph (t)(1)(i) or (t)(1)(ii) of this AD, as applicable.
(i) For airplanes in pre-Airbus Modification 27716 or pre-Airbus Service Bulletin A320-52-1100 configuration: After completing the optional modification specified in paragraph (n)(2) of this AD.
(ii) For airplanes in post-Airbus Modification 27716 or post Airbus Service Bulletin A320-52-1100 configuration: As of the effective date of this AD.
(2) Do not install on any airplane a component specified in paragraphs (g)(1) through (g)(5) of this AD or paragraphs (i)(1) through (i)(3) of this AD, as required by paragraph (t)(2)(i) or (t)(2)(ii) of this AD, as applicable.
(i) For airplanes in pre-Airbus Modification 155648 or pre-Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, configuration: After completion of the additional work required by paragraph (r) of this AD.
(ii) For airplanes in post-Airbus Modification 155648 or post-Airbus Service Bulletin A320-52-1165, Revision 03, excluding Appendix 01 and including Appendix 02, dated November 9, 2017, configuration: As of the effective date of this AD.
(1) This paragraph provides credit for optional actions provided by paragraph (n)(2) of this AD, if those actions were performed before the effective date of this AD using Airbus Service Bulletin A320-52-1100, dated December 7, 1998.
(2) This paragraph provides credit for the actions required by paragraphs (g), (i), (k), (l), and (m) of this AD, if those actions were performed before the effective date of this AD using Airbus Service Bulletin A320-52-1163, dated February 4, 2014.
(3) This paragraph provides credit for the actions required by paragraphs (k), (l)(1), (m), and (n)(3) of this AD if those actions were performed before the effective date of this AD using Airbus Service Bulletin A320-52-1165, Revision 01, dated October 23, 2015, excluding Appendix 01, dated November 3, 2014, and including Appendix 02, dated October 23, 2015.
(1)
(i) Before using any approved AMOC, notify your appropriate principal inspector, or lacking a principal inspector, the manager of the local flight standards district office/certificate holding district office.
(ii) AMOCs approved previously for AD 2016-07-23 are approved as AMOCs for the corresponding provisions of this AD.
(2)
(3)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA AD 2018-0023, dated January 26, 2018; corrected February 5, 2018; for related information. This MCAI may be found in the AD docket on the internet at
(2) For more information about this AD, contact Sanjay Ralhan, Aerospace Engineer, International Section, Transport Standards Branch, FAA, 2200 South 216th St., Des Moines, WA 98198; telephone and fax 206-231-3223.
(3) For service information identified in this AD, contact Airbus SAS, Airworthiness Office—EIAS, Rond-Point Emile Dewoitine No: 2, 31700 Blagnac Cedex, France; telephone +33 5 61 93 36 96; fax +33 5 61 93 44 51; email
Federal Energy Regulatory Commission.
Notice of proposed rulemaking.
The Federal Energy Regulatory Commission (Commission) is proposing to amend its regulations to incorporate by reference, with certain enumerated exceptions, the latest version (Version 3.1) of business practice standards adopted by the Wholesale Gas Quadrant of the North American Energy Standards Board (NAESB) applicable to natural gas pipelines in place of the currently incorporated version (Version 3.0) of those business practice standards.
Comments are due October 1, 2018.
Comments, identified by the docket number of this proceeding, may be filed electronically at
1. The Federal Energy Regulatory Commission (Commission) proposes to amend its regulations at 18 CFR 284.12 to incorporate by reference, with certain enumerated exceptions,
2. Since 1996, the Commission has adopted regulations to standardize the business practices and communication methodologies of interstate natural gas pipelines to create a more integrated and efficient pipeline grid. These regulations have been promulgated in the Order No. 587 series of orders,
3. On September 29, 2017, NAESB filed a report informing the Commission that it had adopted and ratified WGQ Version 3.1 of its business practice standards applicable to natural gas pipelines. The NAESB report identifies all the changes made to the Version 3.0 Standards and summarizes the deliberations that led to the changes being made. It also identifies changes to the existing standards that were considered but not adopted due to a lack of consensus or other reasons.
4. In this NOPR, the Commission proposes to incorporate by reference, in its regulations, Version 3.1 of the NAESB WGQ consensus business practice standards, with certain exceptions.
5. As the Commission found in Order No. 587, adoption of consensus standards is appropriate, because the consensus process helps ensure the reasonableness of the standards by requiring that the standards draw support from a broad spectrum of industry participants representing all segments of the industry. Moreover, because the industry conducts business under these standards, the Commission's regulations should reflect those standards that have the widest possible support. In section 12(d) of the National Technology Transfer and Advancement Act of 1995, Congress affirmatively requires federal agencies to use technical standards developed by voluntary consensus standards organizations, like NAESB, as a means to carry out policy objectives or activities.
6. We discuss below some specific aspects of NAESB's filing.
7. NAESB adopted two substantive revisions concerning the Nominations Related Standards, which govern shipper requests to schedule service on
That portion of the scheduled quantity that would have theoretically flowed up to the effective time of the intraday nomination being confirmed, based upon a cumulative uniform hourly quantity for each nomination period affected.
NAESB also provides the following further clarification of these concepts in the description of the technical implementation of business processes included as part of Standard 1.4.1, where NAESB explains that:
[a] “Pathed” nomination is actually a “Pathed Threaded” nomination because (1) the physical path of the pipeline locations and service contract(s) is fully described in the nomination, and (2) the logical thread of a specific supplier entity to a specific market entity at specific pipeline locations for a specific quantity is also fully described. “Non-Pathed” nominations are actually “Non-Pathed Non-Threaded” nominations because (1) physical “location location-to to-location” paths are not described in the nominations, and (2) no ties of specific supply entities to specific market entities are established. And for “Pathed Non-Threaded” nominations, (1) the physical path of the pipeline locations, service contract(s), and quantity is fully described, and (2) no ties of specific supply entities to specific market entities are established.
8. NAESB also adopted three revisions to the WGQ Electronic Delivery Mechanism Standards, which establish the framework for the electronic dissemination and communication of information between parties in the North American Wholesale Gas marketplace. First, NAESB revised Standard 4.3.80 to increase the allowable field length in ASCII Comma Separated Value Files to 3000 characters because that increases the amount of information that can be conveyed, but reasonably limits it in conformity with commonly used software such as Excel. Second, NAESB adopted new Standard 4.3.106 to allow checkboxes and radio buttons in the Transmission Service Providers' Electronic Bulletin Boards (EBBs) to indicate “Yes” and/or “No” responses to data elements, which is more convenient than the current drop down list. Third, NAESB modified its standards to update the operating systems and web browsers that entities should support to allow users to take advantage of recent developments in computer technology and use. Additionally, language was added to clarify the Secure Sockets Layer/Transport Layer Security protocols, which encrypt data to hide information from electronic observers on the internet. The new standard provides guidance on the timing for adoption of a new version of Secure Sockets Layer/Transport Layer Security protocols—new versions of these protocols should be used within 9 months of the version becoming generally available. In addition, the new standard clarifies that Secure Sockets Layer is a colloquial term that encompasses both Secure Sockets Layer and Transport Layer Security.
9. Other changes adopted by NAESB included changes to the NAESB WGQ data sets and other technical implementation documentation, which provide the technological support necessary to use the NAESB standards effectively. One such change was to add a new Business Conditional data element “Agent” and corresponding technical implementation to the Nomination data set Standard 1.4.1 and the Scheduled Quantity data set Standard 1.4.5. Currently, in the data sets, the Service Requester is defined as the Shipper or their Agent; however, language included in the implementation guides states that both the Shipper and Agent will be identified. Thus, this change adds a data element “Agent” to the data sets to allow the Service Requestor to identify both the shipper and its agent if it uses an agent to nominate and schedule on the pipeline.
10. NAESB also adopted revisions to the Flowing Gas Related data sets and technical implementation, which address quantitative issues relating generally to allocation, imbalances and measurement of flowing gas. Specifically, NAESB added three Business Conditional data elements to the Authorization to Post Imbalances data set (Standard 2.4.9). The addition of the three data elements will allow a Service Requester to authorize specific contracts and quantities of imbalances for specified periods of time to be posted.
11. In addition, NAESB revised the Imbalance Trade data set (Standard 2.4.11) to reinstate language providing the confirming party the ability to reject a trade in the Imbalance Trade data set when an auto-confirm agreement with a confirming party is in place. NAESB states that in its WGQ Version 2.1 publication, before the Imbalance Trading data sets were consolidated, the Imbalance Trade Confirmation contained a Yes/No indicator that the confirming party could use to indicate its acceptance or rejection of the trade. This indicator informed a pipeline whether the confirming party agreed to the terms of the trade that the initiating trader had posted. When the data sets were consolidated, this data element was dropped because it was assumed that if a confirming party did not agree with the posted terms it would not confirm the trade, which was effective only if the pipeline did not have an auto-confirm agreement with that confirming party. Accordingly, to address situations where there are auto-confirm agreements, NAESB has now revised Standard 2.4.11 to add a new Business Conditional data element “Imbalance Trade Response” with an “Accept/Reject” code value. This Accept/Reject indicator informs the pipeline whether the confirming party agrees to the terms of the trade that the initiating trader had posted.
12. NAESB also revised Standard 2.4.6 to add two Senders Option data elements,
13. NAESB also adopted revisions to the Capacity Release Related data sets and technical implementation. Specifically, NAESB revised Standard 5.4.24 to add a new Business Conditional data element, “Waive Bidder Credit Indicator” and corresponding code values to the Offer data set. The additional data element indicates to a Bidder whether the Releasing Shipper will waive, pursuant to the Transmission Service Provider's tariff, the Bidder's creditworthiness pre-qualification.
14. Further, NAESB revised Standard 6.3.1 (
15. Lastly, NAESB adopted modifications to the cover page of Standard 6.3.1 to add a self-identification provision that assists end users in determining whether counterparties are commercial market participants as defined by the United States Commodity Futures Trading Commission.
16. The Commission proposes to continue its past practice
17. The Commission is proposing to continue the compliance filing requirements as revised in Order No. 587-V.
18. Consistent with our practice in Order No. 587-V, each pipeline should designate a single tariff section under which every NAESB WGQ Standard incorporated by reference by the Commission is listed.
19. Consistent with our findings in Order No. 587-V,
20. If the pipeline is requesting a continuation of an existing waiver or extension of time, it must include a table in its transmittal letter that identifies the standard for which a waiver or extension of time was granted, and the docket number or order citation to the proceeding in which the waiver or extension of time was granted. The pipeline must also present an explanation for why such waiver or extension of time should remain in force with regard to the WGQ Version 3.1 Standards.
21. This continues the Commission's practice of having pipelines include in their tariffs a common location that identifies the way the pipeline is incorporating all the NAESB WGQ Standards and the standards with which it is required to comply. As explained above, the Commission will post on its eLibrary website (under Docket No. RM96-1-041) a sample tariff format, to provide filers an illustrative example to aid them in preparing their compliance filings.
22. Office of Management and Budget Circular A-119 (section 11) (February 10, 1998) provides that Federal Agencies should publish a request for comment in a NOPR when the agency is seeking to issue or revise a regulation proposing to adopt a voluntary consensus standard or a government-unique standard. In this NOPR, the Commission is proposing to incorporate by reference voluntary consensus standards developed by the WGQ.
23. The Office of the Federal Register requires agencies incorporating material by reference in final rules to discuss, in the preamble of the final rule, the ways that the materials it incorporates by reference are reasonably available to interested parties and how interested parties can obtain the materials.
24. The WGQ Additional Business Practice Standards address six areas: Creditworthiness, Storage Information, Gas/Electric Operational Communications, Operational Capacity, Unsubscribed Capacity, and Location Data Download.
• The Creditworthiness related standards describe requirements for the exchange of information, notification, and communication between parties during the creditworthiness evaluation process.
• The Storage Information related standards define the information to be provided to natural gas service requesters related to storage activities and/or balances.
• The Gas/Electric Operational Communications related standards define communication protocols intended to improve coordination between the gas and electric industries in daily operational communications between transportation service providers and gas-fired power plants. The standards include requirements for communicating anticipated power generation fuel for the upcoming day as well as any operating problems that might hinder gas-fired power plants from receiving contractual gas quantities.
• The Operational Capacity related standards define requirements of the transportation service provider related to the reporting and requesting of a transportation service provider's operational capacity, total scheduled quantity, and operationally available capacity.
• The Unsubscribed Capacity related standards define requirements of the transportation service provider related to reporting and requesting a transportation service provider's available unsubscribed capacity.
• The Location Data Download related standards define requirements for the use of codes assigned by the transportation service provider for locations and common codes for parties communicating electronically.
25. The WGQ Nominations Related Business Practice Standards define the process by which a natural gas service requester with a natural gas transportation contract nominates (or requests) service from a pipeline or a transportation service provider for the delivery of natural gas.
26. The WGQ Flowing Gas Related Business Practice Standards define the business processes related to the communication of entitlement rights of flowing gas at a location, of the entitlement rights on a contractual basis, of the management of imbalances, and of the measurement and gas quality information of the actual flow of gas.
27. The Invoicing Related Business Practice Standards define the process for the communication of charges for services rendered (Invoice), communication of details about funds rendered in payment for services rendered (Payment Remittance), and communication of the financial status of a customer's account (Statement of Account).
28. The Quadrant Electronic Delivery Mechanism Related Business Practice Standards define the framework for the electronic dissemination and communication of information between parties in the North American wholesale gas marketplace for Electronic Data Interchange (EDI)/Electronic Delivery Mechanism (EDM) transfers, batch flat file/EDM transfers, informational postings websites, EBB/EDM and interactive flat file/EDM.
29. The Capacity Release Related Business Practice Standards define the business processes for communication of information related to the selling of all or any portion of a transmission service requester's contract rights.
30. The internet Electronic Transport Related Business Practice Standards define the implementation of various technologies necessary to communicate transactions and other electronic data using standard protocols for electronic commerce over the internet between trading partners.
31. Our regulations provide that copies of the standards incorporated by reference may be obtained from the North American Energy Standards Board, 801 Travis Street, Suite 1675, Houston, TX 77002, Phone: (713) 356-0060. Copies of the standards may be inspected at the Federal Energy Regulatory Commission, Public Reference and Files Maintenance Branch, 888 First Street NE, Washington, DC 20426, Phone: (202) 502-8371,
32. NAESB is a private consensus standards developer that develops voluntary wholesale and retail standards related to the energy industry. The procedures used by NAESB make its standards reasonably available to those affected by Commission regulations, which generally is comprised of entities that have the means to acquire the information they need to effectively participate in Commission proceedings. Participants can join NAESB, for an annual membership cost of $7,000, which entitles them to full participation in NAESB and enables them to obtain these standards at no additional cost. Non-members may obtain the Individual Standards Manual or Booklets for each of the seven Manuals by email for $250 per manual, which in the case of these standards would total $1,750. Non-members also may obtain the complete set of Standards Manuals, Booklets, and Contracts on USB flash drive for $2,000. NAESB also provides a free electronic read-only version of the standards for a three business day period or, in the case of a regulatory comment period, through the end of the comment period. In addition, NAESB considers requests for waivers of the charges on a case-by-case basis depending on need.
33. The Office of Management and Budget (OMB) regulations require that OMB approve certain reporting, record keeping, and public disclosure requirements (information collection) imposed by an agency.
34. The Commission solicits comments on the Commission's need for this information, whether the information will have practical utility, the accuracy of the provided burden estimates, ways to enhance the quality, utility, and clarity of the information to be collected, and any suggested methods for minimizing respondents' burden, including the use of automated information techniques.
35.
36. The collections of information related to this NOPR fall under FERC-545 (Gas Pipeline Rates: Rate Change (Non-Formal))
The one-time burden (for both the FERC-545 and FERC-549C) will be averaged over three years:
Computer and Information Systems Manager (Occupation Code: 11-3021), $96.51
Electrical Engineer (Occupation Code: 17-2071), $66.90
Legal (Occupation Code: 23-0000), $143.68
The average hourly cost (salary plus benefits), weighting all of these skill sets evenly, is $102.36. The Commission rounds it to $102/hour.
The number of responses is also averaged over three years (for both the FERC-545 and FERC-549C):
The responses and burden for Years 1-3 will total respectively as follows:
The implementation of these data requirements will provide additional transparency to informational posting websites and will improve communication standards. The implementation of these standards and regulations will promote the additional efficiency and reliability of the natural gas industries' operations thereby helping the Commission to carry out its responsibilities under the Natural Gas Act. In addition, the Commission's Office of Enforcement will use the data for general industry oversight.
37. Interested persons may obtain information on the reporting requirements by contacting the following: Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 [Attention: Ellen Brown, Office of the Executive Director],
38. Comments concerning the collection of information(s) and the associated burden estimate(s), should be sent to the contact listed above and to the Office of Management and Budget, Office of Information and Regulatory Affairs, Washington, DC 20503 [Attention: Desk Officer for the Federal Energy Regulatory Commission, telephone: (202) 395-0710, fax: (202) 395-4718].
39. The Commission is required to prepare an Environmental Assessment or an Environmental Impact Statement for any action that may have a significant adverse effect on the human environment.
40. The Regulatory Flexibility Act of 1980 (RFA)
41. Approximately 165 interstate natural gas pipelines, both large and small, are potential respondents subject to the requirements adopted by this rule. Most of the natural gas pipelines regulated by the Commission do not fall within the RFA's definition of a small entity,
42. Accordingly, pursuant to 605(b) of the RFA,
43. The Commission invites interested persons to submit comments on the matters and issues proposed in this document to be adopted, including any related matters or alternative proposals that commenters may wish to discuss. Comments are due October 1, 2018. Comments must refer to Docket No. RM96-1-041, and must include the commenter's name, the organization they represent (if applicable), and their address in their comments.
44. The Commission encourages comments to be filed electronically via the eFiling link on the Commission's website at
45. Commenters that are not able to file comments electronically must send an original of their comments to: Federal Energy Regulatory Commission, Secretary of the Commission, 888 First Street NE, Washington, DC 20426.
46. All comments will be placed in the Commission's public files and may be viewed, printed, or downloaded remotely as described in the Document Availability section below. Commenters on this proposal are not required to serve copies of their comments on other commenters.
47. In addition to publishing the full text of this document in the
48. From the Commission's Home Page on the internet, this information is available on eLibrary. The full text of this document is available on eLibrary in PDF and Microsoft Word format for viewing, printing, and/or downloading. To access this document in eLibrary, type the docket number excluding the last three digits of this document in the docket number field.
49. User assistance is available for eLibrary and the Commission's website during normal business hours from the Commission's Online Support at (202) 502-6652 (toll free at 1-866-208-3676) or email at
Incorporation by reference, Natural gas, Reporting and recordkeeping requirements.
By direction of the Commission.
In consideration of the foregoing, the Commission proposes to amend part 284, chapter I, title 18,
15 U.S.C. 717-717z, 3301-3432; 42 U.S.C. 7101-7352; 43 U.S.C. 1331-1356.
The revision reads as follows:
(a) * * *
(1) An interstate pipeline that transports gas under subparts B or G of this part must comply with the business practices and electronic communications standards as promulgated by the North American Energy Standards Board, as incorporated herein by reference in paragraphs (a)(1)(i) thru (vii) of this section.
(i) Additional Standards (Version 3.1, September 29, 2017);
(ii) Nominations Related Standards (Version 3.1, September 29, 2017);
(iii) Flowing Gas Related Standards (Version 3.1, September 29, 2017);
(iv) Invoicing Related Standards (Version 3.1, September 29, 2017);
(v) Quadrant Electronic Delivery Mechanism Related Standards (Version 3.1, September 29, 2017);
(vi) Capacity Release Related Standards (Version 3.1, September 29, 2017); and
(vii) internet Electronic Transport Related Standards (Version 3.1, September 29, 2017).
Environmental Protection Agency (EPA).
Proposed rule.
The Environmental Protection Agency (EPA) is proposing to approve portions of three state implementation plan (SIP) revisions submitted by the State of California to meet Clean Air Act (CAA or “the Act”) requirements for the 2008 8-hour ozone national ambient air quality standards (NAAQS or “standards”) in the San Joaquin Valley, California ozone nonattainment area. First, the EPA is proposing to approve the portions of the
Written comments must arrive on or before October 1, 2018.
Submit your comments, identified by Docket ID No. EPA-R09-OAR-2018-0535 at
Laura Lawrence, EPA Region IX, (415) 972-3407,
Throughout this document, “we,” “us” and “our” refer to the EPA.
Ground-level ozone pollution is formed from the reaction of volatile organic compounds (VOC) and oxides of nitrogen (NO
Scientific evidence indicates that adverse public health effects occur following exposure to ozone, particularly in children and adults with lung disease. Breathing air containing ozone can reduce lung function and inflame airways, which can increase respiratory symptoms and aggravate asthma or other lung diseases.
Under section 109 of the CAA, the EPA promulgates NAAQS for pervasive air pollutants, such as ozone. The EPA has previously promulgated NAAQS for ozone in 1979 and 1997.
Following promulgation of a new or revised NAAQS, the EPA is required under CAA section 107(d) to designate areas throughout the country as attaining or not attaining the NAAQS. The San Joaquin Valley was designated as nonattainment for the 2008 ozone standards on May 21, 2012, and classified as Extreme.
Under the CAA, after the EPA designates areas as nonattainment for a NAAQS, states with nonattainment areas are required to submit SIP revisions that provide for, among other things, attainment of the NAAQS within certain prescribed periods that vary depending on the severity of nonattainment. Areas classified as Extreme must attain the NAAQS within 20 years of the effective date of the nonattainment designation.
In California, the California Air Resources Board (CARB or “State”) is the state agency responsible for the adoption and submission to the EPA of California SIPs and SIP revisions, and it has broad authority to establish emissions standards and other requirements for mobile sources. Local and regional air pollution control districts in California are responsible for the regulation of stationary sources and are generally responsible for the development of regional air quality plans. In the San Joaquin Valley, the San Joaquin Valley Air Pollution Control District (SJVAPCD or “District”) develops and adopts air quality management plans to address CAA planning requirements applicable to that region. Such plans are then submitted to CARB for adoption and submittal to the EPA as revisions to the California SIP.
The San Joaquin Valley nonattainment area for the 2008 ozone standards consists of San Joaquin, Stanislaus, Merced, Madera, Fresno, Tulare, and Kings counties, and the western portion of Kern County. The San Joaquin Valley nonattainment area stretches over 250 miles from north to south, averages a width of 80 miles, and encompasses over 23,000 square miles. It is partially enclosed by the Coast Mountain range to the west, the Tehachapi Mountains to the south, and the Sierra Nevada range to the east.
The population of the San Joaquin Valley in 2015 was estimated to be nearly 4.2 million people, and is projected to increase by 25.3 percent in 2030 to over 5.2 million people.
States must implement the 2008 ozone standards under Title 1, part D of the CAA, which includes section 172 (“Nonattainment plan provisions in general”) and sections 181-185 of subpart 2 (“Additional Provisions for Ozone Nonattainment Areas”). To assist states in developing effective plans to address ozone nonattainment problems, in 2015 the EPA issued a SIP Requirements Rule (SRR) for the 2008 ozone standards (“2008 Ozone SRR”) that addresses
The EPA's 2008 Ozone SRR was challenged, and on February 16, 2018, the U.S. Court of Appeals for the D.C. Circuit (“D.C. Circuit”) published its decision in
On August 24, 2016, in response to the area's designation as nonattainment and classification of Extreme for the 2008 ozone NAAQS, CARB submitted the 2016 Ozone Plan to the EPA as a revision to the California SIP.
The 2016 Ozone Plan submittal consists of documents originating from the District (
The 2016 Ozone Plan discusses compliance with the emission statement requirement under CAA section 182(a)(3)(B) in terms of District Rule 1160, “Emission Statements.” District Rule 1160 was adopted by the District on November 18, 1992, and submitted to the EPA by CARB on January 11, 1993, as a revision to the California SIP.
In approving the 2016 Ozone Plan, CARB anticipated the subsequent adoption of a commitment by CARB to achieve an aggregate emission reduction of 8 tons per day (tpd) of NO
CAA sections 110(a)(1) and (2) and 110(l) require a state to provide reasonable public notice and opportunity for public hearing prior to the adoption and submission of a SIP or SIP revision. To meet this requirement, every SIP submittal should include evidence that adequate public notice was given and an opportunity for a public hearing was provided consistent with the EPA's implementing regulations in 40 CFR 51.102.
Both the District and CARB have satisfied the applicable statutory and regulatory requirements for reasonable public notice and hearing prior to the adoption and submittal of the 2016 Ozone Plan, the 2016 State Strategy, and District Rule 1160. With respect to the 2016 Ozone Plan, the District conducted a public workshop on May 23, 2014, and held two additional workshops on March 22, 2016, on the Draft 2016 Ozone Plan. On May 11, 2016, the District published notices in several local newspapers of a public hearing to be held on June 16, 2016, for the adoption of the 2016 Ozone Plan.
CARB also provided the required public notice and opportunity for public comment on the 2016 Ozone Plan. On June 17, 2016, CARB released for public review its staff report for the 2016 Ozone Plan and published a notice of public meeting to be held on July 21, 2016, to consider approval of the 2016 Ozone Plan.
With respect to the 2016 State Strategy, on May 17, 2016, CARB circulated for public review and comment the Proposed State SIP Strategy, provided a 60-day comment period, and provided notice of a public hearing by the CARB Board to be held on September 22, 2016. On March 7, 2017, in response to comments received during the public comment period and
With respect to District Rule 1160, the District conducted four public workshops to receive comment, and published notices in several local newspapers of a public hearing to be held on November 18, 1992. The District adopted the rule on November 18, 1992, and forwarded the rule to CARB for approval and submittal to the EPA as a revision to the California SIP. CARB did so by letter dated January 11, 1993.
Based on information provided in each SIP revision and summarized above, the EPA has determined that all hearings were properly noticed. Therefore, we find that the submittals of the 2016 Ozone Plan, the 2016 State Strategy, and District Rule 1160 meet the procedural requirements for public notice and hearing in CAA sections 110(a) and 110(l) and 40 CFR 51.102.
CAA sections 172(c)(3) and 182(a)(1) require states to submit for each ozone nonattainment area a “base year inventory” that is a comprehensive, accurate, current inventory of actual emissions from all sources of the relevant pollutant or pollutants in the area. In addition, the 2008 Ozone SRR requires that the inventory year be selected consistent with the baseline year for the RFP demonstration, which is usually the most recent calendar year for which a complete triennial inventory is required to be submitted to the EPA under the Air Emissions Reporting Requirements.
The base year and future year baseline inventories for NO
The emissions inventories in the 2016 Ozone Plan were developed jointly by CARB and the District, based on data from these two agencies, combined with data from the California Department of Transportation, the Department of Motor Vehicles, the Department of Pesticide Regulation, the California Energy Commission and regional transportation agencies. The emissions inventories reflect actual emission reports for point sources, and estimates for mobile and area-wide sources are based on the most recent models and methodologies. CARB and the District also reviewed the growth profiles for point and area-wide source categories and updated them as necessary to ensure that the emission projections are based on data that reflect historical trends, current conditions, and recent economic and demographic forecasts.
CARB developed the emissions inventory for on-road and off-road mobile sources. On-road mobile source emissions, which include passenger vehicles, buses, and trucks, were estimated using CARB's EMFAC2014 model. The on-road emissions were calculated by applying EMFAC2014 emission factors to the transportation activity data provided by the local San Joaquin Valley transportation agencies from their 2014 adopted Regional Transportation Plan. The EPA has approved this model for use in SIPs and transportation conformity analyses.
The 2012 inventory was projected to 2015 and future years using CARB's California Emission Projection Analysis Model (CEPAM). The District identified several measures that achieve emissions reductions from stationary sources in and after 2012, including rules for open burning, boilers, flares, solid fuel boilers, and glass melting furnaces, among others.
As described elsewhere, the 2008 Ozone SRR requires the base year inventory to be consistent with the RFP baseline year inventory; accordingly, the 2016 Ozone Plan uses the year 2012 for the base year inventory and the RFP baseline year inventory. The EPA has evaluated the 2012 base year inventory and the methodologies used by the District and CARB, and we find them to be comprehensive, accurate, and current. However, as discussed elsewhere, we are not taking action at this time to approve the base year emissions inventory or the emissions inventories for any of the RFP milestone years in the 2016 Ozone Plan. We intend to take action on the base year emissions inventory at a later time, together with the RFP demonstration, and other elements affected by the
However, we note that the attainment demonstration and VMT offset demonstration rely on the 2012 base year inventory. As discussed in section III.D of this proposed action, the EPA's draft modeling guidance states that the EPA does not require a particular year to be used for the base year for modeling purposes. The most appropriate base year may be the most recent year of the National Emissions Inventory, or it may be selected in view of unusual meteorology, transport patterns, or other factors that may vary from year to year.
Section 182(a)(3)(B)(i) of the Act requires states to submit a SIP revision requiring owners or operators of stationary sources of VOC or NO
The preamble of the 2008 Ozone SRR states that if an area has a previously approved emission statement rule for the 1997 ozone NAAQS or the 1-hour ozone NAAQS that covers all portions of the nonattainment area for the 2008 ozone NAAQS, such rule should be sufficient for purposes of the emission statement requirement for the 2008 ozone NAAQS.
The District adopted Rule 1160, “Emission Statements,” on November 18, 1992, to address the SIP submittal requirements for emission statements for areas such as San Joaquin Valley that were designated as nonattainment for the 1-hour ozone NAAQS under the CAA Amendments of 1990. CARB submitted District Rule 1160 to the EPA on January 11, 1993.
District Rule 1160 applies to all owners and operators of any stationary source category that emits or may emit VOC or NO
The 2016 Ozone Plan concludes that District Rule 1160 continues to meet the emission statement requirements of CAA section 182(a)(3)(B) and relies on that rule to meet the emission statement requirements for the 2008 ozone standards.
As noted previously, the EPA has not taken action on CARB's January 11, 1993 submittal of District Rule 1160 but is proposing to do so herein. First, we
We also note that, while District Rule 1160 provides authority to the District to waive the requirement for any class or category of stationary sources that emit less than 25 tpy, such a waiver is allowed under CAA section 182(a)(3)(B)(ii) so long as the state includes estimates of such class or category of stationary sources in base year emissions inventories and periodic inventories submitted under CAA sections 182(a)(1) and 182(a)(3)(A), based on EPA emissions factors or other methods acceptable to the EPA. We recognize that emissions inventories developed by CARB for San Joaquin Valley routinely include actual emissions estimates for all stationary sources or classes or categories of such sources, including those less than 25 tpy, and that such inventories provide the basis for inventories submitted to meet the requirements of CAA sections 182(a)(1) and 182(a)(3)(A). By approval of emissions inventories as meeting the requirements of CAA sections 182(a)(1) and 182(a)(3)(A), the EPA is implicitly accepting the methods and factors used by CARB to develop those emissions estimates. Our most recent approval of a base year emissions inventory for San Joaquin Valley is found at 77 FR 12652 (March 1, 2012) (approval of base year emissions inventory for the 1997 ozone NAAQS).
Thus, for the reasons stated above, we propose to approve District Rule 1160, which CARB submitted on January 11, 1993, as meeting the emission statement requirements under CAA section 182(a)(3)(B). For more detailed information concerning our evaluation of District Rule 1160, please see the related technical support document.
CAA section 172(c)(1) requires that each attainment plan provide for the implementation of all RACM as expeditiously as practicable (including such reductions in emissions from existing sources in the area as may be obtained through implementation of reasonably available control technology), and also provide for attainment of the NAAQS. The 2008 Ozone SRR requires that, for each nonattainment area required to submit an attainment demonstration, the state concurrently submit a SIP revision demonstrating that it has adopted all RACM necessary to demonstrate attainment as expeditiously as practicable and to meet any RFP requirements.
The EPA has previously provided guidance interpreting the RACM requirement in the General Preamble for the Implementation of the Clean Air Act Amendments of 1990 and in a memorandum entitled “Guidance on the Reasonably Available Control Measure Requirement and Attainment Demonstration Submissions for Ozone Nonattainment Areas.”
CAA section 172(c)(6) requires that nonattainment area plans include enforceable emission limitations, and such other control measures, means or techniques (including economic incentives such as fees, marketable permits, and auctions of emission rights), as well as schedules and timetables for compliance, as may be necessary or appropriate to provide for timely attainment of the NAAQS.
For the 2016 Ozone Plan, the District, CARB, and the local metropolitan planning organizations (MPOs) each undertook a process to identify and evaluate potential RACM that could contribute to expeditious attainment of the 2008 Ozone NAAQS in the San Joaquin Valley. We describe each agency's efforts below.
The District's RACM demonstration and control strategy for the 2008 ozone NAAQS focuses on stationary and area source controls and is described in Chapter 5, Chapter 6 and Appendix C of the 2016 Ozone Plan. To identify potential RACM, the District reviewed 59 control measures for a number of source categories and compared its measures against federal requirements and regulations implemented by the State and other air districts. In the years prior to the adoption of the 2016 Ozone Plan, the District developed and implemented comprehensive plans to provide for attainment of the NAAQS
Table 2 identifies the District control measures listed in table 5-1 of the 2016 Ozone Plan, which contribute toward attainment of the 2008 ozone NAAQS by 2031. The EPA has approved all of these measures into the California SIP.
The District provides a more comprehensive evaluation of its RACM control strategy in Appendix C of the 2016 Ozone Plan, which provides the following:
• Description of the sources within the category or sources subject to the rule;
• Base year and projected baseline year emissions for the source category affected by the rule;
• Discussion of the current requirements of the rule; and
• Discussion of potential additional control measures, including, in many cases, a discussion of the technological and economic feasibility of the additional control measures. This includes comparison of each District rule to analogous control measures adopted by other agencies (including the EPA, the South Coast Air Quality Management District, and the Bay Area Air Quality Management District).
We provide more detailed information about these control measures in our technical support document.
Based on its evaluation of all of these measures, the District concludes that it is implementing all RACM for sources under the District's jurisdiction.
Chapters 5 and 6 of the 2016 Ozone Plan contain CARB's evaluation of mobile source and other statewide control measures that reduce emissions of NO
Given the need for substantial emissions reductions from mobile and area sources to meet the NAAQS in California nonattainment areas, the State of California has been a leader in the development of stringent control measures for on-road and off-road mobile sources and the fuels that power them. California has unique authority under CAA section 209 (subject to a waiver by the EPA) to adopt and implement new emission standards for many categories of on-road vehicles and engines, and new and in-use off-road vehicles and engines.
Historically, the EPA has allowed California to take into account emissions reductions from CARB regulations for which the EPA has issued waiver or authorizations under CAA section 209, notwithstanding the fact that these regulations have not been approved as part of the California SIP. However, in response to the decision by
CARB's mobile source program extends beyond regulations that are subject to the waiver or authorization process set forth in CAA section 209 to include standards and other requirements to control emissions from in-use heavy-duty trucks and buses, gasoline and diesel fuel specifications, and many other types of mobile sources. Generally, these regulations have been submitted and approved as revisions to the California SIP.
While all of the identified State control measures contribute to some degree to attainment of the 2008 ozone standards in the San Joaquin Valley, some measures are identified in particular in the 2016 Ozone Plan as providing significant emissions reductions relied upon for attainment of the 2008 ozone standards. These measures include the On-Road Heavy-Duty Diesel In-Use Regulation, the Low Emission Vehicle III and Zero Emission Vehicle Regulation, and the Heavy-Duty Truck Idling Requirements.
The 2016 Ozone Plan concludes that, in light of the comprehensiveness and stringency of CARB's mobile source program, all RACM for mobile sources under CARB's jurisdiction are being implemented, and that no additional measure would advance attainment of the 2008 ozone NAAQS by at least a year.
The local jurisdictions' RACM analysis was conducted by the eight MPOs in the San Joaquin Valley and is provided in Appendix D of the 2016 Ozone Plan.
The process followed by the District in the 2016 Ozone Plan to identify RACM is generally consistent with the EPA's recommendations in the General Preamble. The process included compiling a comprehensive list of potential control measures for sources of NO
We have reviewed the District's determination in the 2016 Ozone Plan that its stationary and area source control measures represent RACM for NO
With respect to mobile sources, we recognize CARB as a leader in the development and implementation of stringent control measures for on-road and off-road mobile sources, and its current program addresses the full range of mobile sources in the San Joaquin Valley through regulatory programs for both new and in-use vehicles. With respect to transportation controls, we note that the MPOs have a program to fund cost-effective TCMs. Overall, we believe that the programs developed and administered by CARB and the MPOs provide for the implementation of RACM for NO
In the 2016 Ozone Plan, the District estimated that it would take a reduction of 2.7 tpd of NO
Section 182(c)(2)(A) of the Clean Air Act requires that a plan for an ozone nonattainment area classified Serious or above include a “demonstration that the plan . . . will provide for attainment of the ozone [NAAQS] by the applicable attainment date. This attainment demonstration must be based on photochemical grid modeling or any other analytical method determined . . . to be at least as effective.” The attainment demonstration predicts future ambient concentrations for comparison to the NAAQS, making use of available information on measured concentrations, meteorology, and current and projected emissions inventories of ozone precursors, including the effect of control measures in the plan.
Areas classified Extreme for the 2008 ozone NAAQS must demonstrate attainment as expeditiously as practicable, but no later than 20 years after the effective date of designation as nonattainment. The San Joaquin Valley was designated nonattainment effective July 20, 2012, and the area must demonstrate attainment of the standards by July 20, 2032.
The EPA's recommended procedures for modeling ozone as part of an attainment demonstration are contained in
To ensure that the model achieves accurate results based on relevant atmospheric phenomena, without errors that compensate each other to give just the appearance of accuracy, and to guide refinement of model inputs, it is also recommended to assess, at least to some extent, if the model correctly represents the underlying physical and chemical processes. This can be done via
Unlike the RFP demonstration and the emissions inventory requirements, the 2008 SRR does not specify that a specific year must be used for the modeled base year for the attainment demonstration. The Modeling Guidance also does not require a particular year to be used as the base year for 8-hour ozone plans.
CARB performed the air quality modeling for the 2016 Ozone Plan with assistance from the District. The modeling relies on a 2012 base year and demonstrates attainment in 2031. The Plan's modeling protocol is in Appendix I of the 2016 Ozone Plan and contains all the elements recommended in the Modeling Guidance. Those include: Selection of model, time period to model, modeling domain, and model boundary conditions and initialization procedures; a discussion of emissions inventory development and other model input preparation procedures; model performance evaluation procedures; selection of days and other details for calculating RRFs; and provisions for archival and access to raw model inputs and outputs.
The modeling and modeled attainment demonstration are described in Chapter 4 of the 2016 Ozone Plan and in more detail in Appendix H, which provides a description of model input preparation procedures and various model configuration options. Appendix J of the 2016 Ozone Plan provides the coordinates of the modeling domain and thoroughly describes the development of the modeling emissions inventory, including its chemical speciation, its spatial and temporal allocation, its temperature dependence, and quality assurance procedures. The modeling analysis used version 5 of the Community Multiscale Air Quality (CMAQ) photochemical model, developed by the EPA. The 2007 version of the State-wide Air Pollution Research Center chemical mechanism (SAPRC07) was used within CMAQ. SAPRC07 is an update to a mechanism that has been used for the San Joaquin Valley and other areas of the US, and it has been peer-reviewed as discussed in the protocol. To prepare meteorological input for CMAQ, the Weather and Research Forecasting model version 3.6 (WRF) from the National Center for Atmospheric Research was used. The overall WRF meteorological modeling domain covers California's neighboring states, and major portions of the next outer ring of states, with 36-kilometer (km) resolution (
The WRF meteorological model results and performance statistics are described in Appendix H, section 3.2. Supplemental figures S.1-S.20 provide hourly time series graphs of wind speed, direction, and temperature for the Northern, Central, and Southern sub-
As recommended in the Modeling Guidance, the 2016 Ozone Plan also provided a phenomenological evaluation of the meteorological modeling, assessing its ability to replicate qualitative features of the area's meteorological phenomena that could be important for ozone concentrations. The 2016 Ozone Plan's evaluation confirmed that the model was able to capture important phenomena such as up-slope and down-slope flows in the mountain ranges surrounding the Central Valley, and the split in flow toward north and south as winds enter the Central Valley through the Sacramento River delta area.
Ozone model performance statistics are described in the 2016 Ozone Plan at Appendix H, section 5.2. That section includes tables of statistics recommended in the Modeling Guidance for 8-hour and 1-hour daily maximum ozone for the three San Joaquin Valley sub-regions. Supplemental figures S.21-S.102 provide frequency distributions, scatterplots, and hourly time series graphs of ozone concentrations for each of the 25 monitors located in the San Joaquin Valley. The supplemental hourly time series show generally good performance, though many individual daily ozone peaks are underpredicted. This is confirmed by the ozone frequency distributions (
As noted in the 2016 Ozone Plan's modeling protocol, the Modeling Guidance recognizes that limited time and resources can constrain the extent of the diagnostic and dynamic evaluation of model performance undertaken.
As for meteorological performance, the Modeling Guidance cautions against pass/fail tests, in favor of an overall confidence assessment and identification of causes of poor performance to help guide refinement of model input.
After model performance for the 2012 base case was accepted, the model was applied to develop RRFs for the attainment demonstration.
The 2016 Ozone Plan carried out the attainment test procedure consistent with the Modeling Guidance. The RRFs were calculated as the ratio of future to base year concentrations. This was done for each monitor using the top 10 ozone days over 0.060 ppm,
The 2016 Ozone Plan includes an additional attainment demonstration using “banded” RRFs.
Finally, the 2016 Ozone Plan modeling includes an “Unmonitored Area Analysis” to assess the attainment status of locations other than monitoring sites.
In addition to the formal attainment demonstration, the Plan also contains a WOE analysis in Appendix K. Some of the contents of Appendix K have already been discussed above,
The modeling shows that existing CARB and District control measures are sufficient to attain the 2008 8-hour Ozone NAAQS by 2031 at all monitoring sites in the San Joaquin Valley. Given the extensive discussion of modeling procedures, tests, and performance analyses called for in the Modeling Protocol and the good model performance, the EPA finds that the modeling is adequate for purposes of supporting the attainment demonstration. The EPA finds that the State has demonstrated attainment of the NAAQS by the applicable attainment date, and we propose to approve the attainment demonstration provided in the 2016 Ozone Plan.
Requirements for RFP are specified in CAA sections 172(c)(2), 182(b)(1), and 182(c)(2)(B). CAA section 172(c)(2) requires that plans for nonattainment areas provide for RFP, which is defined as such annual incremental reductions in emissions of the relevant air pollutant as are required under part D (“Plan Requirements for Nonattainment Areas”) or may reasonably be required by the EPA for the purpose of ensuring attainment of the applicable NAAQS by the applicable date. CAA section 182(b)(1) specifically requires that ozone nonattainment areas that are classified as Moderate or above demonstrate a 15 percent reduction in VOC between the years of 1990 and 1996. The EPA has typically referred to section 182(b)(1) as the Rate of Progress (ROP) requirement. For ozone nonattainment areas classified as Serious or higher, section 182(c)(2)(B) requires reductions averaged over each consecutive 3-year period beginning 6 years after the baseline year until the attainment date of at least 3 percent of baseline emissions per year. The provisions in CAA section 182(c)(2)(B)(ii) allow an amount less than 3 percent of such baseline emissions each year if the state demonstrates to the EPA that the plan includes all measures that can feasibly be implemented in the area in light of technological achievability.
The 2008 Ozone SRR considers areas classified Moderate or higher to have met the ROP requirements of CAA section 182(b)(1) if the area has a fully approved 15 percent ROP plan for the 1-hour or 1997 8-hour ozone standards, provided the boundaries of the ozone nonattainment areas are the same.
Except as specifically provided in CAA section 182(b)(1)(C), emissions reductions from all SIP-approved, federally promulgated, or otherwise SIP-creditable measures that occur after the baseline are creditable for purposes of demonstrating that the RFP targets are met. Because the EPA has determined that the passage of time has caused the effect of certain exclusions to be
The 2008 Ozone SRR requires the RFP baseline year to be the most recent calendar year for which a complete triennial inventory is required to be submitted to the EPA (
The 2016 Ozone Plan addresses the 15 percent ROP requirement by noting that the EPA approved a 15 percent ROP plan for the 1-hour ozone NAAQS for the San Joaquin Valley in 1997, and that the 1-hour ozone nonattainment area covers the entire nonattainment area for the 2008 ozone standards.
To address the RFP requirements, the 2016 Ozone Plan selected 2012 as the RFP baseline year and provided emissions inventories for the RFP baseline, milestone and attainment years.
We have reviewed the 2016 Ozone Plan and agree that the EPA has approved a 15 percent ROP demonstration for the 1-hour ozone NAAQS, fulfilling the requirements of CAA section 182(b)(1).
For the RFP requirements under CAA sections 172(c)(2) and 182(c)(2)(B), the Ozone SRR established 2011 as the RFP baseline year. As discussed previously, the D.C. Circuit vacated provisions of the 2008 Ozone SRR allowing states to use an alternative RPF baseline year between 2008 and 2012 in lieu of 2011. Because the 2016 Ozone Plan used 2012 as the RFP baseline year, we are not taking action at this time on the RFP demonstration in the 2016 Ozone Plan.
Section 182(d)(1)(A) of the Act requires the state, if subject to its requirements for a given area, to submit a revision that identifies and adopts specific enforceable transportation control strategies and transportation control measures to offset any growth in emissions from growth in vehicle miles traveled (VMT) or number of vehicle trips in such area.
In
The August 2012 guidance discusses the meaning of Transportation Control Strategies (TCSs) and Transportation Control Measures (TCMs) and recommends that both TCSs and TCMs be included in the calculations made for the purpose of determining the degree to which any hypothetical growth in emissions due to growth in VMT should be offset. Generally, TCSs encompass many types of controls including, for example, motor vehicle emissions limitations, I/M programs, alternative fuel programs, other technology-based measures, and TCMs, that would fit within the regulatory definition of “control strategy.”
The August 2012 guidance explains how states may demonstrate that the VMT emissions offset requirement is satisfied in conformance with the Ninth Circuit's ruling. The August 2012 guidance recommends that states estimate emissions for the nonattainment area's base year and attainment year. One emissions inventory is developed for the base year, and three different emissions inventory scenarios are developed for the attainment year. For the attainment year, the state would present three emissions estimates, two of which would represent hypothetical emissions scenarios that would provide the basis to identify the growth in emissions due solely to the growth in VMT, and one that would represent projected actual motor vehicle emissions after fully accounting for projected VMT growth and offsetting emissions reductions obtained by all creditable TCSs and TCMs. See the August 2012 guidance for specific details on how states might conduct the calculations.
The base year on-road VOC emissions should be calculated using VMT in that year, and should reflect all enforceable TCSs and TCMs in place in the base year. This would include vehicle emissions standards, state and local control programs, such as I/M programs or fuel rules, and any additional implemented TCSs and TCMs that were already required by or credited in the SIP as of that base year.
The first of the emissions calculations for the attainment year would be based on the projected VMT and trips for that year and assume that no new TCSs or TCMs beyond those already credited in the base year inventory have been put in place since the base year. This calculation demonstrates how emissions would hypothetically change if no new TCSs or TCMs were implemented, and VMT and trips were allowed to grow at the projected rate from the base year. This estimate would show the potential for an increase in emissions due solely to growth in VMT and trips. This represents a “no action” scenario. Emissions in the attainment year in this scenario may be lower than those in the base year due to fleet turnover; however, if VMT and/or numbers of vehicle trips are projected to increase in the attainment year, emissions would still likely be higher than if VMT had held constant.
The second of the attainment year's emissions calculations would assume that no new TCSs or TCMs beyond those already credited have been put in place since the base year, but it would also assume that there was no growth in VMT and trips between the base year and attainment year. This estimate reflects the hypothetical emissions level that would have occurred if no further TCMs or TCSs had been put in place and if VMT and trip levels had held constant since the base year. Like the “no action” attainment year estimate described above, emissions in the attainment year may be lower than those in the base year due to fleet turnover, but in this case emissions would not be influenced by any growth in VMT or trips. This emissions estimate would reflect a ceiling on the attainment emissions that should be allowed to occur under the statute as interpreted by the Ninth Circuit because it shows what would happen under a scenario in which no offsetting TCSs or TCMs have yet been put in place and VMT and trips are held constant during the period from the area's base year to its attainment year. This represents a “VMT offset ceiling” scenario. These two hypothetical status quo estimates are necessary steps in identifying the target level of emissions from which states determine whether further TCMs or TCSs, beyond those that have been adopted and implemented in reality, would need to be adopted and implemented in order to fully offset any increase in emissions due solely to VMT and trips identified in the “no action” scenario.
Finally, the state would present the emissions that are actually expected to occur in the area's attainment year after taking into account reductions from all enforceable TCSs and TCMs that in reality were put in place after the baseline year. This estimate would be based on the VMT and trip levels expected to occur in the attainment year (
If, instead, the estimated projected actual attainment year emissions are still greater than the ceiling that was established in the second of the attainment year emissions calculations, even after accounting for post-baseline year TCSs and TCMs, the state would need to adopt and implement additional TCSs or TCMs to further offset the growth in emissions. The additional TCSs or TCMs would need to bring the actual emissions down to at least the “had VMT and trips held constant” ceiling estimated in the second of the attainment year calculations, in order to meet the VMT offset requirement of section 182(d)(1)(A) as interpreted by the Ninth Circuit.
CARB prepared the San Joaquin Valley VMT emissions offset demonstration, which is included as section D.3 (“VMT Offsets”) of Appendix D (“Mobile Source Control Strategy”) of the 2016 Ozone Plan. For the demonstration, CARB used EMFAC2014, the latest EPA-approved motor vehicle emissions model for California. The EMFAC2014 model estimates the on-road emissions from two combustion processes (
Emissions from running exhaust, start exhaust, hot soak, and running losses are a function of how much a vehicle is driven. As such, emissions from these processes are directly related to VMT and vehicle trips, and CARB included emissions from them in the calculations that provide the basis for the San Joaquin Valley VMT emissions offset demonstration. CARB did not include emissions from resting loss and diurnal loss processes in the analysis because such emissions are related to vehicle population, not to VMT or vehicle trips, and thus are not part of “any growth in emissions from growth in
The San Joaquin Valley VMT emissions offset demonstration uses 2012 as the base year and also includes the previously described three different attainment year scenarios (
Table 3 summarizes the relevant distinguishing parameters for each of the emissions scenarios and shows CARB's corresponding VOC emissions estimates for the demonstration for the 2008 8-hour ozone NAAQS.
For the base year scenario, CARB ran the EMFAC2014 model for the applicable base year (
For the “no action” scenario, CARB first identified the on-road motor vehicle control programs (
For the “VMT offset ceiling” scenario, CARB ran the EMFAC2014 model for the attainment years but with VMT and starts data corresponding to base year values. Like the no action scenarios, the EMFAC2014 model was adjusted to reflect the VOC emissions levels in the attainment years without the benefits of the post-base-year on-road motor vehicle control programs. Thus, the VMT offset ceiling scenario reflects hypothetical VOC emissions in the San Joaquin Valley if CARB had not put in place any TCSs or TCMs after the base year and if there had been no growth in VMT or vehicle trips between the base year and the attainment year.
The hypothetical growth in emissions due to growth in VMT and trips can be determined from the difference between the VOC emissions estimates under the no action scenario and the corresponding estimates under the VMT offset ceiling scenario. Based on the values in table 3, the hypothetical growth in emissions due to growth in VMT and trips in the San Joaquin Valley would have been 5 tpd (
For the “projected actual” scenario calculation, CARB ran the EMFAC2014 model for the attainment year with VMT and starts data at attainment year values and with the full benefits of the relevant post-baseline year motor vehicle control programs. For this scenario, CARB included the emissions benefits from TCSs and TCMs put in place since the base year. The most significant measures reducing VOC emissions during the 2012 to 2031 timeframe include the Advanced Clean Cars program, Low Emission Vehicles II and III standards, Zero Emissions Vehicle standards, On-Board Diagnostics, Smog Check Improvements, and California Reformulated Gasoline Phase 3.
As shown in table 3, the calculation of the projected actual attainment-year VOC emissions resulted in 14 tpd for the 2008 8-hour ozone NAAQS demonstration. CARB then compared this value against the corresponding VMT offset ceiling value to determine whether additional TCMs or TCSs would need to be adopted and implemented in order to offset any increase in emissions due solely to VMT and trips. Because the projected actual emissions are less than the corresponding VMT offset ceiling emissions, CARB concluded that the demonstration shows compliance with the VMT emissions offset requirement and that there are sufficient adopted TCSs and TCMs to offset the growth in emissions from the growth in VMT and vehicle trips in the San Joaquin Valley for the 2008 8-hour standards. In fact, taking into account the creditable post-baseline year TCMs and TCSs, CARB showed that they offset the hypothetical difference by 8 tpd for the 2008 8-hour standards, rather than the required 5 tpd, respectively.
Based on our review of the San Joaquin Valley VMT emissions offset demonstration in Appendix D of the 2016 Ozone Plan, we find CARB's analysis to be acceptable and agree that CARB has adopted sufficient TCSs and TCMs to offset the growth in emissions from growth in VMT and vehicle trips in the San Joaquin Valley for the purposes of the 2008 8-hour ozone standards. As such, we find that the San Joaquin Valley VMT emissions offset demonstration complies with the VMT emissions offset requirement in CAA section 182(d)(1)(A). Therefore, we propose approval of the San Joaquin Valley VMT emissions offset demonstration portion of the 2016 Ozone Plan.
Under the CAA, 8-hour ozone nonattainment areas classified under subpart 2 as Moderate or above must include in their SIPs contingency measures consistent with sections 172(c)(9) and 182(c)(9). Contingency measures are additional controls or measures to be implemented in the event the area fails to make reasonable further progress or to attain the NAAQS by the attainment date. The SIP should contain trigger mechanisms for the contingency measures, specify a schedule for implementation, and indicate that the measure will be implemented without significant further action by the state or the EPA.
Neither the CAA nor the EPA's implementing regulations establish a specific level of emissions reductions that implementation of contingency measures must achieve, but the EPA's 2008 Ozone SRR reiterates the EPA's policy that contingency measures should provide for emissions reductions approximately equivalent to one year's worth progress, amounting to reductions of 3 percent of the baseline emissions inventory for the nonattainment area.
It has been the EPA's longstanding interpretation of section 172(c)(9) that states may rely on federal measures (
The EPA has approved numerous SIPs under this interpretation—
In its 2016 Ozone Plan, the District set aside NO
The magnitude of contingency measure reductions in the 2016 Ozone Plan is affected by the
CAA section 182(e)(3) provides that SIPs for Extreme nonattainment areas require each new, modified, and existing electric utility and industrial and commercial boiler that emits more than 25 tpy of NO
Additional guidance on this requirement is provided in the General Preamble at 13523. According to the General Preamble, a boiler should generally be considered as any combustion equipment used to produce steam and generally does not include a process heater that transfers heat from combustion gases to process streams.
The 2016 Ozone Plan addresses the requirements of CAA section 182(e)(3) in section 3.17 (“Clean Fuels”) of Chapter 3, and states that District Rules 4305, 4306, and 4352 address NO
Rule 4305 (now titled “Boilers, Steam Generators, and Process Heaters—Phase 2”) was adopted by the District in 1993 and was superseded by Rule 4306 (“Boilers, Steam Generators, and Process Heaters—Phase 3”). Both Rules 4305 and 4306 apply to any gaseous fuel- or liquid fuel-fired boiler, steam generator, or process heater with a rated heat input greater than 5 MMBtu per hour. Rule 4305, as amended on August 21, 2003, was approved by the EPA in 2004, and Rule 4306, as revised on October 16, 2008, was approved by the EPA in 2010.
Rule 4352, titled “Solid Fuel-Fired Boilers, Steam Generators, and Process Heaters” was last approved by the EPA on November 6, 2012.
In addition, new and modified boilers that will emit or have the potential to emit 25 tpy or more of NO
Section 176(c) of the CAA requires federal actions in nonattainment and maintenance areas to conform to the SIP's goals of eliminating or reducing the severity and number of violations of the NAAQS and achieving expeditious attainment of the standards. Conformity to the SIP's goals means that such actions will not: (1) Cause or contribute to violations of a NAAQS, (2) worsen the severity of an existing violation, or (3) delay timely attainment of any NAAQS or any interim milestone.
Actions involving Federal Highway Administration (FHWA) or Federal Transit Administration (FTA) funding or approval are subject to the EPA's transportation conformity rule, codified at 40 CFR part 93, subpart A. Under this rule, MPOs in nonattainment and maintenance areas coordinate with state and local air quality and transportation agencies, the EPA, the FHWA, and the FTA to demonstrate that an area's regional transportation plans and transportation improvement programs conform to the applicable SIP. This demonstration is typically done by showing that estimated emissions from
For motor vehicle emissions budgets to be approvable, they must meet, at a minimum, the EPA's adequacy criteria (40 CFR 93.118(e)(4) and (5)) and be approvable under all pertinent SIP requirements. To meet these requirements, the MVEBs must be consistent with the approvable attainment and RFP demonstrations and reflect all of the motor vehicle control measures contained in the attainment and RFP demonstrations.
The EPA's process for determining adequacy of a MVEB consists of three basic steps: (1) Providing public notification of a SIP submission; (2) providing the public the opportunity to comment on the MVEB during a public comment period; and, (3) making a finding of adequacy or inadequacy.
The 2016 Ozone Plan includes budgets for the 2018, 2021, 2024, 2027, and 2030 RFP milestone years, and the 2031 attainment year. The budgets were calculated using EMFAC2014, CARB's latest approved version of the EMFAC model for estimating emissions from on-road vehicles operating in California, and reflect average summer weekday emissions consistent with the RFP milestone years and the 2031 attainment year for the 2008 8-hour ozone NAAQS.
As discussed above, the MVEBs for 2018, 2021, 2024, 2027 and 2030 derive from the RFP baseline year and the associated RFP milestone years. As such, the budgets are affected by the
The EPA has previously determined that the 2031 budgets in 2016 Ozone Plan are adequate for use for transportation conformity purposes. On February 23, 2017, the EPA announced the availability of the 2016 Ozone Plan and budgets, which were available for a 30-day public comment period that ended on March 27, 2017.
In today's notice, the EPA is proposing to approve only the 2031 budgets in the 2016 Ozone Plan for transportation conformity purposes. The EPA has determined through its review of the submitted 2016 Ozone Plan that the 2031 budgets are consistent with emission control measures in the SIP and attainment in 2031 for the 2008 8-hour ozone NAAQS. For the reasons discussed in section III.D of this proposed rule, we are proposing to approve the attainment demonstration in the 2016 Ozone Plan. The 2031 budgets, as given in table 5, are consistent with the attainment demonstration, are clearly identified and precisely quantified, and meet all other applicable statutory and regulatory requirements, including the adequacy criteria in 93.118(e)(4) and (5). For these reasons, the EPA proposes to approve the budgets in table 5.
CARB has requested that we limit the duration of our approval of the budgets only until the effective date of the EPA's adequacy finding for any subsequently submitted budgets.
• An acknowledgement and explanation as to why the budgets under consideration have become outdated or deficient;
• A commitment to update the budgets as part of a comprehensive SIP update; and
• A request that the EPA limit the duration of its approval to the time when new budgets have been found to be adequate for transportation conformity purposes.
Because CARB's request does not include a commitment to update the budgets or an explanation of why the budgets have become outdated or deficient, we cannot at this time propose to limit the duration of our approval of the submitted budgets until new budgets have been found adequate. In order to limit the approval, we would need the information described above to determine whether such limitation is reasonable and appropriate in this case. Once CARB has adequately addressed that information, we intend to review it and take appropriate action. If we propose to limit the duration of our approval of the MVEB in the 2016 Ozone Plan, we will provide the public an opportunity to comment. The duration of the approval of the budgets, however, would not be limited until we complete such a rulemaking.
In addition to the requirements discussed above, title 1, subpart D of the CAA includes other provisions applicable to Extreme ozone nonattainment areas, such as the San Joaquin Valley. We describe these provisions and their current status below for informational purposes only.
Section 182(c)(3) of the CAA requires states with ozone nonattainment areas classified under subpart 2 as Serious or above to implement an enhanced motor vehicle I/M program in those areas. The requirements for those programs are provided in CAA section 182(c)(3) and 40 CFR part 51, subpart S.
Consistent with the 2008 Ozone SRR, the 2016 Ozone Plan states that no new I/M programs are currently required for nonattainment areas for the 2008 ozone standards.
In accordance with CAA section 211, the federal reformulated gasoline (RFG) program requires certain areas to use gasoline that has been reformulated to reduce emissions of ozone precursors. As an Extreme ozone nonattainment area for the 1-hour ozone NAAQS, the San Joaquin Valley was included in the federal RFG program.
Section 182(a)(2)(C) of the CAA requires states to develop SIP revisions containing permit programs for each of its ozone nonattainment areas. The SIP revisions are to include requirements for permits in accordance with CAA sections 172(c)(5) and 173 for the construction and operation of each new or modified major stationary source for VOC and NO
Sections 182(c)(4)(A) and 246 of the CAA require California to submit to the EPA for approval into the SIP measures to implement a Clean Fuels Fleet Program. Section 182(c)(4)(B) of the CAA allows states to opt-out of the federal clean-fuel vehicle fleet program by submitting a SIP revision consisting of a program or programs that will result in at least equivalent long-term reductions in ozone precursors and toxic air emissions.
In 1994, CARB submitted a SIP revision to the EPA to opt-out of the federal clean-fuel fleet program, and included a demonstration that California's low-emissions vehicle program achieved emissions reductions at least as large as would be achieved by the federal program. The EPA approved the SIP revision to opt-out of the federal
Section 182(b)(3) of the CAA requires states to submit a SIP revision by November 15, 1992, that requires owners or operators of gasoline dispensing systems to install and operate gasoline vehicle refueling vapor recovery (“Stage II”) systems in ozone nonattainment areas classified as Moderate and above. California's ozone nonattainment areas implemented Stage II vapor recovery well before the passage of the CAA Amendments of 1990.
Section 202(a)(6) requires the EPA to promulgate standards requiring motor vehicles to be equipped with onboard refueling vapor recovery (ORVR) systems. The EPA promulgated the first set of ORVR system regulations in 1994 for phased implementation on vehicle manufacturers, and since the end of 2006, essentially all new gasoline-powered light and medium-duty vehicles are ORVR-equipped.
While a SIP submittal meeting CAA section 182(b)(3) is not required for the 2008 ozone standards, under California State law (
In the San Joaquin Valley, the installation and operation of CARB-certified vapor recovery equipment is required and enforced by District Rules 4621 (“Gasoline Transfer into Stationary Storage Containers, Delivery Vessels and Bulk Plants”) and 4622 (“Gasoline Transfer into Motor Vehicle Fuel Tanks”). The most recent versions of Rules 4621 and 4622, amended on December 19, 2013, have been approved into the California SIP.
Section 182(c)(1) of the CAA requires that all ozone nonattainment areas classified as Serious or above implement measures to enhance and improve monitoring for ambient concentrations of ozone, NO
On November 10, 1993, CARB submitted to the EPA a SIP revision addressing the PAMS network for six ozone nonattainment areas in California, including the San Joaquin Valley, to meet the enhanced monitoring requirements of CAA section 182(c)(1). The EPA determined that the PAMS SIP revision met all applicable requirements for enhanced monitoring and the EPA PAMS regulations and approved the PAMS submittal into the California SIP.
The 2016 Ozone Plan discusses compliance with the EPA's enhanced monitoring requirements in 40 CFR part 58, and concludes that, based on the EPA's approval of the District's air monitoring network plan, the San Joaquin Valley meets all federal ambient monitoring requirements.
The 2016 Ozone Plan reports that the Arvin-Bear Mountain PAMS monitoring site in the Bakersfield MSA was closed in 2010, and would resume once a permanent air monitoring site in the area was established. The closed monitoring site at Arvin-Bear Mountain was relocated to a new site at the Arvin-Di Giorgio elementary school. CARB's staff report for the 2016 Ozone Plan includes, for approval by the EPA, provisions to address ambient ozone monitoring in the Bakersfield MSA.
Prior to 2006, the EPA's ambient air monitoring regulations in 40 CFR part 58 (“Ambient Air Quality Surveillance”) set forth specific SIP requirements (
Section 185 of the CAA requires that the SIP for each Severe and Extreme ozone nonattainment area provide that, if the area fails to attain by its applicable attainment date, each major stationary source of VOC and NO
The 2016 Ozone Plan relies on control measures, such as state and district rules and regulations, that have been adopted and are being implemented to demonstrate attainment of the 2008 ozone NAAQS by 2031. However, in the 2016 Ozone Plan, the District also notes that newer NAAQS,
The District has committed to amend Rule 4311 for flares and Rule 4694 for wine fermentation and storage tanks to include additional requirements to reduce emissions to the extent those controls are technologically achievable or economically feasible; however, these commitments were made in the context of attainment of future ozone and PM
The 2016 Ozone Plan references additional reductions anticipated from CARB's mobile source state strategy, a draft of which was released in October 2015.
As noted above, the attainment demonstration in the 2016 Ozone Plan relies on adopted measures, rather than committal measures. Thus, CARB's regulatory initiative commitment and aggregate emission reduction commitment for San Joaquin Valley are not needed as part of the control strategy for the 2008 ozone NAAQS in San Joaquin Valley. However, the commitments by CARB for San Joaquin Valley in the 2016 State Strategy will strengthen the SIP by providing emissions reductions that supplement the reductions from the adopted controls; therefore, we are proposing to approve the San Joaquin Valley portions of the 2016 State Strategy into the SIP.
For the reasons discussed above, under CAA section 110(k)(3), the EPA is proposing to approve as a revision to the California SIP the following portions of the San Joaquin Valley 2016 Ozone Plan
• RACM demonstration as meeting the requirements of CAA section 172(c)(1) and 40 CFR 51.1112(c);
• ROP demonstration as meeting the requirements of CAA section 182(b)(1);
• Attainment demonstration as meeting the requirements of CAA section 182(c)(2)(A) and 40 CFR 51.1108;
• Enhanced monitoring as meeting the requirements of CAA section 182(c)(1) and 40 CFR 51.1102;
• Enhanced vehicle inspection and maintenance programs as meeting the
• Provisions for clean fuels or advanced control technology for boilers as meeting the requirements of CAA section 182(e)(3) and 40 CFR 51.1102;
• VMT emissions offset demonstration as meeting the requirements of CAA section 182(d)(1)(A) and 40 CFR 51.1102; and
• Motor vehicle emissions budgets for the attainment year of 2031 (see table 5, above) because they are consistent with the attainment demonstration proposed for approval herein and meet the other criteria in 40 CFR 93.118(e).
In addition, we are proposing to approve District Rule 1160 titled “Emission Statements” submitted by CARB on January 11, 1993, as a revision to the California SIP because it meets all the applicable requirements for emission statements and to approve the Emission Statement section of the 2016 Ozone Plan as meeting the requirements of CAA section 182(a)(3)(B) and 40 CFR 51.1102.
Finally, we are proposing to approve, as additional measures that strengthen the SIP, the San Joaquin Valley portions of the 2016 State Strategy and CARB's aggregate emission reduction commitment of 8 tpd of NO
We are not taking action at this time on the base year emissions inventory, the RFP demonstration, the motor vehicle emissions budgets for RFP milestone years, and contingency measures portions of the 2016 Ozone Plan. We intend to propose action on these elements at a later time.
The EPA is soliciting public comments on the issues discussed in this document. We will accept comments from the public on this proposal for the next 30 days and will consider comments before taking final action.
In this action, the EPA is proposing to include in a final EPA rule regulatory text that includes incorporation by reference. In accordance with requirements of 1 CFR 51.5, the EPA is proposing to incorporate by reference District Rule 1160 as described in section III.B of this preamble. The EPA has made, and will continue to make, these materials available through
Under the Clean Air Act, the Administrator is required to approve a SIP submission that complies with the provisions of the Act and applicable federal regulations. 42 U.S.C. 7410(k); 40 CFR 52.02(a). Thus, in reviewing SIP submissions, the EPA's role is to approve state choices, provided that they meet the criteria of the Clean Air Act. Accordingly, this proposed action merely proposes to approve state plans and an air district rule as meeting federal requirements and does not impose additional requirements beyond those imposed by state law. For that reason, this proposed action:
• Is not a “significant regulatory action” subject to review by the Office of Management and Budget under Executive Orders 12866 (58 FR 51735, October 4, 1993) and 13563 (76 FR 3821, January 21, 2011);
• Is not an Executive Order 13771 (82 FR 9339, February 2, 2017) regulatory action because SIP approvals are exempted under Executive Order 12866;
• Does not impose an information collection burden under the provisions of the Paperwork Reduction Act (44 U.S.C. 3501
• Is certified as not having a significant economic impact on a substantial number of small entities under the Regulatory Flexibility Act (5 U.S.C. 601
• Does not contain any unfunded mandate or significantly or uniquely affect small governments, as described in the Unfunded Mandates Reform Act of 1995 (Pub. L. 104-4);
• Does not have Federalism implications as specified in Executive Order 13132 (64 FR 43255, August 10, 1999);
• Is not an economically significant regulatory action based on health or safety risks subject to Executive Order 13045 (62 FR 19885, April 23, 1997);
• Is not a significant regulatory action subject to Executive Order 13211 (66 FR 28355, May 22, 2001);
• Is not subject to requirements of section 12(d) of the National Technology Transfer and Advancement Act of 1995 (15 U.S.C. 272 note) because application of those requirements would be inconsistent with the Clean Air Act; and
• Does not provide the EPA with the discretionary authority to address disproportionate human health or environmental effects with practical, appropriate, and legally permissible methods under Executive Order 12898 (59 FR 7629, February 16, 1994).
In addition, the SIP is not approved to apply on any Indian reservation land or in any other area where the EPA or an Indian tribe has demonstrated that a tribe has jurisdiction. In those areas of Indian country, the proposed rule does not have tribal implications and will not impose substantial direct costs on tribal governments or preempt tribal law as specified by Executive Order 13175 (65 FR 67249, November 9, 2000).
Environmental protection, Air pollution control, Incorporation by reference, Intergovernmental relations, Nitrogen dioxide, Ozone, Reporting and recordkeeping requirements, Volatile organic compounds.
42 U.S.C. 7401
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Proposed rule, request for comments.
NMFS proposes regulations to implement measures in Amendment 20 to the Atlantic Mackerel, Squid, and Butterfish Fishery Management Plan and corrections to existing regulations. This action is necessary to prevent the reactivation of latent effort in the longfin squid fishery, preserve economic opportunities for more recently active participants in the longfin squid fishery, avoid overharvest during Trimester II (May-August) of the longfin squid fishery, and reduce potential negative impacts on inshore spawning longfin squid aggregations and squid egg masses. The Mid-Atlantic Fishery Management Council intends that these proposed measures would
Public comments must be received by October 1, 2018.
You may submit comments on this document, identified by NOAA-NMFS-2017-0110, by either of the following methods:
1. Go to
2. Click the “Comment Now!” icon, complete the required fields, and
3. Enter or attach your comments.
A draft environmental assessment (EA) has been prepared for this action that describes the proposed measures and other considered alternatives and the potential impacts of such measures and alternatives. Copies of the specifications document, including the EA and the Initial Regulatory Flexibility Analysis, are available on request from Dr. Christopher M. Moore, Executive Director, Mid-Atlantic Fishery Management Council, 800 North State Street, Suite 201, Dover, DE 19901, telephone (302) 674-2331. The EA/Regulatory Impact Review (RIR)/Regulatory Flexibility Act (RFA) analysis is also accessible via the internet at
Written comments regarding the burden-hour estimates or other aspects of the collection-of-information requirements contained in this proposed rule may be submitted to the Greater Atlantic Regional Fisheries Office and by email to
Douglas Christel, Fishery Policy Analyst, (978) 281-9141,
In 1995, the Mid-Atlantic Fishery Management Council (Council) adopted and NMFS approved a limited access permit system for longfin squid and butterfish as part of Amendment 5 to the Atlantic Mackerel, Squid, and Butterfish Fishery Management Plan (FMP) (April 2, 1996; 61 FR 14465). Under Amendment 5, NMFS issued longfin squid/butterfish moratorium permits to vessels that landed a minimum amount of either species during a specified qualification period. Since then, the number of vessels landing longfin squid has decreased, with a relatively small portion of vessels issued longfin squid/butterfish moratorium permits landing the majority of longfin squid in recent years. The Council is concerned that unused longfin squid/butterfish moratorium permits could be activated, which could lead to excessive fishing effort and bycatch of both longfin squid and non-target species. This could cause negative biological impacts to these species. In addition, this increased effort could increase the race to fish and reduce access to available longfin squid quota by vessels with a continuous history of landings in recent years. Therefore, the Council developed Amendment 20 to consider adjusting the number of vessels qualified to fish in the directed and incidental longfin squid fishery and design appropriate measures to prevent unanticipated increases in fishing effort. The proposed measures described below could help prevent a race to fish, frequent and disruptive fishery closures, and reduced fishing opportunities for vessels that are more recently dependent upon longfin squid.
Longfin squid spawning occurs year round but is most frequently observed inshore during the late spring through early fall. Spawning aggregations and associated egg masses (mops) that are attached to the bottom are vulnerable to bottom fishing activities during the summer months when longfin squid are easily accessible to the fishery in large concentrations. In 2007, the Council implemented reduced quotas during summer months (May through August, or Trimester II) as part of the trimester quota system (January 30, 2007; 71 FR 4211). The Council developed the trimester quota system to improve the monitoring and management of the longfin squid fishery and prevent allowable quotas from being exceeded. Once a trimester quota has been landed, possession limits are reduced to incidental levels for all longfin squid permits. The FMP currently includes a 2,500 lb (1,134 kg) possession limit per trip for incidental permits and for all longfin squid permits when the directed fishery has closed once a quota has been landed. However, this incidental limit has allowed vessels to continue to land large amounts of longfin squid even after the directed fishery is closed, and has contributed to the Trimester II quota being exceeded by large amounts in several years. The Council is concerned that excessive fishing effort inshore during Trimester II could negatively impact the stock, interrupting spawning activity, increasing the mortality of squid eggs, and reducing future recruitment. Measures developed by the Council under this action are intended to adjust the management of longfin squid during Trimester II primarily to reduce impacts to spawning squid and egg mops.
From March through May 2015, the Council held scoping meetings from Rhode Island through New Jersey to discuss these issues and develop responsive measures. After further development and analysis, the Council conducted public hearings in April and May 2017 to solicit input on the range of alternatives under consideration by the Council. The Council accepted public comments through May 18, 2017. On June 7, 2017, the Council adopted final measures as part of Amendment 20 to the Atlantic Mackerel, Squid, and Butterfish FMP. On March 21, 2018, the Council submitted the amendment and draft EA to NMFS for preliminary review, with submission of the final draft amendment on June 6, 2018. NMFS drafted the proposed regulations to implement these measures for Council review. The Council deemed the proposed regulations to be necessary and appropriate to implement Amendment 20 on April 27, 2018, as specified in section 303(c) of the Magnuson-Stevens Fishery Conservation and Management Act (Magnuson-Stevens Act).
The purpose of Amendment 20 is to reduce latent (unused) effort in the longfin squid fishery and adjust the management of the longfin squid fishery during Trimester II (May through
Under the Magnuson-Stevens Act, we are required to publish proposed rules for comment after preliminarily determining whether they are consistent with applicable law. The Magnuson-Stevens Act allows us to approve, partially approve, or disapprove measures that the Council proposes based only on whether the measures are consistent with the fishery management plan, plan amendment, the Magnuson-Stevens Act and its National Standards, and other applicable law. Otherwise, we must defer to the Council's policy choices. We are seeking comments on the Council's proposed measures in Amendment 20 described below and whether they are consistent with the Atlantic Mackerel, Squid, and Butterfish FMP, the Magnuson-Stevens Act and its National Standards, and other applicable law.
This proposed rule includes changes to existing FMP measures adopted by the Council under Amendment 20, but also several revisions to regulations that are not specifically identified in Amendment 20. These revisions are necessary to effectively implement the provisions in Amendment 20, or to correct errors in, or clarify, existing provisions. NMFS is proposing these latter changes under the authority of section 305(d) of the Magnuson-Stevens Act.
Amendment 5 created a joint longfin squid/butterfish moratorium permit based on the historic overlap between the directed longfin squid and butterfish fisheries. NMFS issued moratorium permits to qualified vessels based on a minimum landings amount of either species during the qualification period. To reduce capacity in the longfin squid fishery without unintentionally reducing domestic fishing capacity for butterfish, Amendment 20 proposes to separate the longfin squid/butterfish moratorium permit into two moratorium permits, one for each species. Amendment 20 would create a new butterfish moratorium permit and a separate, revised longfin squid moratorium permit, as described further below.
Under Amendment 20, all entities currently issued a longfin squid/butterfish moratorium permit would be automatically issued a new and separate butterfish moratorium permit. The existing permit restrictions and vessel trip report (VTR), observer, slippage, and transfers at sea requirements currently applicable to the existing longfin squid/butterfish moratorium permit would apply to the proposed new butterfish moratorium permit. These permits would maintain the existing vessel permit baseline characteristics, vessel replacement and upgrade provisions, and the restriction on permit splitting; be required to submit vessel trip reports on a weekly basis; and be subject to measures to address slippage and transfers at sea specified at 50 CFR 648.11(n)(3) and 648.13, respectively. Vessels issued a new butterfish moratorium permit would not be required to submit a specific butterfish trip declaration using the vessel monitoring system (VMS) or submit daily VMS catch reports of butterfish but would be required to maintain an operational VMS unit to provide NMFS with automatic position reports. Finally, the existing butterfish possession limits specified at § 648.26(d)(1) and (2) (unlimited when fishing with a mesh size of three inches (76 mm) or greater, and 5,000 lb (2,268 kg) per trip when fishing with less than three-inch (76-mm) mesh) would remain the same for this new permit.
Amendment 20 proposes to re-qualify current longfin squid moratorium permits based on recent landings history to reduce the potential for the reactivation of latent fishing permits. Under this measure, NMFS would issue a new Tier 1 longfin squid moratorium permit only to 2018 longfin squid/butterfish moratorium permits that landed at least 10,000 lb (4,536 kg) of longfin squid in any year from 1997-2013. The Regional Administrator would use fishing history, as documented through dealer reports, to re-qualify permits, including permits currently held in confirmation of permit history (CPH), and automatically issue Tier 1 longfin squid moratorium permits to qualified entities.
Any vessel owner could apply for a Tier 1 longfin squid permit within one year of the effectiveness of this permit, if approved under Amendment 20. A vessel owner that does not qualify to be issued a new Tier 1 longfin squid moratorium permit would be notified by the Regional Administrator and could appeal that decision within 30 days of the denial notice. An appeal would require a written request to the Regional Admininstrator, and the appeal would be reviewed by the NOAA Fisheries National Appeals Office. Appeals could be based upon evidence that the information used in the original denial was incorrect. During an appeal, a vessel owner could request the Regional Administrator to authorize its vessel to continue fishing for longfin squid under the measures for a Tier 1 permit until that appeal is completed.
A vessel issued a Tier 1 longfin squid moratorium permit would be subject to all measures applicable to the existing longfin squid/butterfish moratorium permit, including, but not limited to, the vessel baseline and upgrade, VTR and VMS reporting, observer, slippage, and transfers at sea requirements. A Tier 1 longfin squid moratorium permit would be able to land an unlimited amount of longfin squid per trip, unless the directed longfin squid fishery is closed and incidental limits are implemented, as described further below. As currently allowed for longfin squid/butterfish moratorium permits, Tier 1 permits could also possess up to 15,000 lb (6,804 kg) of longfin squid per trip after the longfin squid fishery is closed in Trimester II, provided the vessel is declared into the
Although the Council chose to reduce latent longfin squid permits, it also wanted to recognize the historic participation of permits that originally qualified for a longfin squid/butterfish moratorium permit. To do so, Amendment 20 would create a separate longfin squid moratorium permit with a moderate possession allowance. The Regional Administrator would automatically issue a Tier 2 longfin squid moratorium permit to any vessel currently issued a 2018 longfin squid/butterfish moratorium permit or an entity issued such a permit in CPH that does not qualify for a Tier 1 longfin squid moratorium permit described above. A Tier 2 permit would be subject to all measures applicable to the
Under Amendment 20, the Council wanted to reduce incentives to target longfin squid under an incidental permit, while still preserving more recent fishing patterns and minimizing discards of squid caught while targeting other species. Under this measure, NMFS would issue a new Tier 3 longfin squid moratorium permit to vessels previously issued an open access squid/butterfish incidental catch permit in any year that landed more than 5,000 lb (2,268 kg) of longfin squid in at least one calendar year from 1997-2013 based on dealer landings data. By limiting access to this incidental permit such that it could not be dropped and re-issued at any time, this measure would prevent a vessel owner from canceling his/her Federal permit to fish for longfin squid in state waters above Federal limits during the fishing year. This would better control longfin squid landings, particularly after a closure of the fishery in Trimester II.
A vessel owner must apply for a Tier 3 longfin squid moratorium permit by submitting an application to the Regional Administrator within one year of the effectiveness of these permits, if approved under Amendment 20. The owner of a vessel permit that does not qualify for a new Tier 3 longfin squid moratorium permit would be notified by the Regional Administrator and could appeal that decision within 30 days of the denial notice. An appeal would require a written request to the Regional Admininstrator, and the appeal would be reviewed by the NOAA Fisheries National Appeals Office. Appeals could be based upon evidence that the information used in the original denial was incorrect. During an appeal, a vessel owner could request the Regional Administrator to authorize its vessel to continue fishing for longfin squid under the measures for a Tier 3 longfin squid permit until that appeal is completed.
A vessel issued a Tier 3 longfin squid permit would be subject to all measures applicable to the existing squid/butterfish incidental catch permit. Unlike Tier 1 or 2 longfin squid moratorium permits, Tier 3 permits would not be issued a vessel baseline, and would not be subject to the vessel upgrade provisions. A Tier 3 longfin squid moratorium permit would be able to land up to 2,500 lb (1,134 kg) of longfin squid per trip, unless the directed longfin squid fishery is closed during Trimester II and incidental limits are implemented, as described further below.
Amendment 20 would allow an owner of more than one longfin squid/butterfish moratorium permit as of May 26, 2017, a one-time opportunity to move longfin squid moratorium permits onto a different vessel that they own to optimize their fishing operations. Under this measure, a vessel owner could move a qualified Tier 1 longfin squid moratorium permit from one of his/her vessels and place it on another vessel that is owned by that same entity and also issued a Tier 2 longfin squid moratorium permit. In this exchange, the Tier 2 longfin squid moratorium permit would be moved onto the vessel originally issued the Tier 1 longfin squid moratorium permit. This allows a vessel owner to “swap” Tier 1 and Tier 2 longfin squid moratorium permits among vessels owned by that entity such that the Tier 1 longfin squid moratorium permit is placed on a vessel that is better able to capitalize on the longfin squid fishing opportunities available to such a permit than the other vessel. This measure is intended to help maximize potential fishing opportunities and associated revenue for entities that have been issued multiple longfin squid moratorium permits on separate vessels and mitigate the loss of revenue potential associated with a permit that does not re-qualify for a Tier 1 longfin squid moratorium permit.
Only permits issued to vessels owned by the same business entity as of May 26, 2017, would be able to participate in the permit swap; a permit held in CPH as of May 26, 2017, would not be eligible to participate. May 26, 2017, is the day that June 2017 Council meeting materials, including the description of proposed measures, were made available to the public. The Council chose this date to limit eligibility for permit swaps to reduce the potential that business entities would change permit ownership to take advantage of this measure and circumvent the purpose of this measure.
Vessels involved in the swap would also need to be within 10 percent of the baseline length overall and 20 percent of the baseline horsepower of the permit to be placed on that vessel. Only Tier 1 and Tier 2 longfin squid moratorium permits could be transferred as part of this permit swap; no other fishery permits could be swapped as part of this transaction. An owner interested in swapping permits would need to apply for the permit swap within one year of the issuance of the Tier 1 or Tier 2 longfin squid moratorium permits. If approved, the Regional Administrator would distribute a permit swap application form to permit holders.
Amendment 20 would reduce the longfin squid possession limit from 2,500 lb (1,134 kg) per trip to 250 lb (113 kg) per trip for vessels issued an open access squid/butterfish incidental permit. A lower incidental possession limit would reduce incentives to target longfin squid and more effectively control fishing effort and landings in the fishery. This could reduce overall fishing effort and bycatch and associated mortality on longfin squid and other species.
This action would also reduce the longfin squid incidental limit for all longfin squid permits from 2,500 lb (1,134 kg) per trip to 250 lb (113 kg) per trip once the Trimester II quota has been landed. The longfin squid incidental limit would remain 2,500 lb (1,134 kg) per trip for any closure implemented during Trimesters I or III. In recent years, excessive landings under the current incidental trip limit (2,500 lb (1,134 kg)) following the closure of the directed fishery in Trimester II has resulted in substantial overages of the Trimester II quota. This measure would reduce incentives to target longfin squid after such a closure, reducing bycatch of longfin squid and other species and impacts to spawning squid and egg mops during Trimester II.
In § 648.2, the term “Northeast Regional Office” in the definition of “Atlantic Mackerel, Squid, and Butterfish Monitoring Committee” would be revised to “Greater Atlantic Regional Fisheries Office” to accurately
In § 648.4(a)(5)(iii), paragraph (B) would be revised to reflect the mackerel landing limit in kg instead of mt, and paragraphs (C), (D), (E), (H) would be revised and paragraph (M) would be deleted to eliminate outdated and unnecessary permit eligibility, application, qualification, baseline, and appeal regulations, respectively, related to the 2011 qualification of limited access mackerel permits.
In § 648.7, text at (a)(1)(i) and (ii) that was inadvertently deleted in the final rule implementing the Mid-Atlantic Unmanaged Forage Omnibus Amendment (August 28, 2017; 82 FR 40721) would be reinserted.
In § 648.10(e)(5)(i), the phrase “. . . or monkfish fishery” would be replaced with “monkfish, or any other fishery” to maintain consistency with other language in this paragraph and related text in paragraph (e)(5)(ii). This revision is necessary to ensure that a vessel that is subject to VMS requirements in any fishery accurately declares its intended fishing operations before leaving port.
In § 648.13, paragraph (a) would be revised to clarify that longfin squid,
In § 648.14, five corrections are proposed, as follows:
1. The introductory text to paragraph (g)(1)(i) would be revised to insert reference to the fishery closure and accountability measure regulations at § 648.24(d) and to replace “Take, retain . . .” with “Take and retain . . .” The first correction is to ensure that this prohibition can be effectively administered and enforced and accurately reflects notifications associated with the implementation of specifications, closures, and accountability measures. The second correction restores the original language of this prohibition to accurately reflect its intent to allow vessels that may encounter these species during normal operations to interact with and discard these species, as appropriate.
2. Paragraph (g)(1)(ii)(B) would be revised to use the term “
3. Paragraph (g)(2)(i) would be revised to reference Subpart B instead of § 648.22 to ensure that the general prohibition applies to all Atlantic Mackerel, Squid, and Butterfish FMP measures, not just those implemented via the specifications process because FMP measures are implemented via framework adjustments, amendments, and specifications actions.
4. Paragraphs (g)(2)(ii)(D) and (F) would be revised to read that it is unlawful for any person owning or operating a vessel issued a valid mackerel, squid, and butterfish fishery permit, or issued an operator's permit to “Take and retain, possess, or land” these species instead of “Take, retain, possess, or land” these species. This distinction is necessary to allow vessels that may encounter these species during normal operations to interact with and discard these species, as appropriate, consistent with Council intent.
5. Paragraph (g)(2)(v) would be revised to replace “limited access” with “directed” to reference the Atlantic mackerel, longfin squid, and
In § 648.22, several corrections are proposed. In paragraph (a), species headings would be added to clarify which elements are to be specified for each species during the specifications process and to spell out terms used for the first time in the regulations. The term “
In § 648.25(a)(4)(i), the reference to paragraph (a)(2) would be replaced with the accurate reference to paragraph (a)(3) of that section.
Pursuant to section 304(b)(1)(A) of the Magnuson-Stevens Act, the NMFS Assistant Administrator has determined that this proposed rule is consistent with Amendment 20 to the Atlantic Mackerel, Squid, and Butterfish FMP, other provisions of the Magnuson-Stevens Act, and other applicable law, subject to further consideration after public comment.
This proposed rule has been determined to be not significant for the purposes of Executive Order 12866.
This proposed rule does not contain policies with Federalism or takings implications as those terms are defined in E.O. 13132 and E.O. 12630, respectively.
The Council prepared a draft EA for this action that analyzes the impact of measures contained in this proposed rule. The EA includes an IRFA, as required by section 603 of the RFA, which is supplemented by information contained in the preamble of this proposed rule. The IRFA, as summarized below, describes the economic impact this proposed rule, if adopted, would have on small entities. A description of the action, why it is being considered, and the legal basis for this action are contained in the preamble to this proposed rule. A copy of the RFA analysis is available from the Mid-Atlantic Council (see
The purpose of this action is to optimize management measures in the squid fisheries by reducing latent (unused) effort in the longfin squid fishery and adjusting the management of the longfin squid fishery during Trimester II (May through August) to avoid overharvesting the longfin squid resource. Section 4.0 of the EA prepared for this action (see
The legal basis and objectives for this action are contained in the preamble to this proposed rule, and are not repeated here. Sections 4.0 and 5.0 of the EA prepared for this action (see
For the purposes of the RFA analysis, the ownership entities (or firms), not the individual vessels, are considered to be the regulated entities. Ownership entities are defined as those entities or firms with common ownership personnel as listed on the permit application. Because of this, some vessels with Federal longfin squid/butterfish permits may be considered to be part of the same firm because they may have the same owners. The North American Industry Classification
The proposed action would affect any vessel issued a valid Federal longfin squid/butterfish moratorium permit or an open access squid/butterfish incidental permit. According to the commercial database, 295 separate vessels were issued a longfin squid/butterfish moratorium permit in 2016. These vessels were owned by 222 entities, of which 214 were categorized as small business entities using the definition specified above. In 2016, 1,528 vessels were issued an open access squid/butterfish incidental permit. These vessels were owned by 1,114 entities, of which 1,105 were small business entities. In total, 1,319 small business entities may be affected by this rule out of a potential 1,336 entities (large and small) that may be affected by this action. Therefore, 99 percent of affected entities are categorized as small businesses.
Not all entities potentially affected by this action landed fish for commercial sale in 2016. Nine small business entities issued a longfin squid/butterfish moratorium permit did not have any fishing revenue in 2016, while 274 small business entities issued an open access squid/butterfish incidental catch permit did not have any fishing revenue in 2016. Only 1,036 small business entities had fishing revenue in 2016, representing 79 percent of the small entities potentially affected by this action.
This proposed rule contains collection-of-information requirements subject to review and approval by the Office of Management and Budget (OMB) under the Paperwork Reduction Act (PRA). This requirement has been submitted to OMB for approval. Public reporting burden and costs associated with these information collections, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data needed, and completing and reviewing the collection of information, are estimated to average, as follows:
1. Application for a longfin squid moratorium permit, OMB #0648-0679 (60 min/response and an annual cost of $254.80 for postage);
2. Appeal of the denial of a longfin squid moratorium permit, OMB #0648-0679 (120 min/response and an annual cost of $226.87 for postage); and
3. Application for a longfin squid moratorium permit swap, OMB #0648-0679 (5 min/response and an annual cost of $1.63 for postage).
Public comment is sought regarding: Whether this proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information shall have practical utility; the accuracy of the burden estimate; ways to enhance the quality, utility, and clarity of the information to be collected; and ways to minimize the burden of the collection of information, including through the use of automated collection techniques or other forms of information technology. Send comments on these or any other aspects of the collection of information to the Greater Atlantic Regional Fisheries Office at the
This proposed rule does not duplicate, overlap, or conflict with any other Federal rule.
Section 7.5 of the EA estimates the number of vessel permits that would qualify under each alternative and the associated economic impacts to affected entities based on recent landings, with additional analysis provided in Section 12 of the EA. The text below summarizes the economic impacts for significant non-selected alternatives.
Under Amendment 20, the Council considered five alternatives, including the no-action alternative, to reduce latent permits in the longfin squid fishery through the creation of a tiered permit system based on historical participation in the fishery. The alternatives included different combinations of qualifying years (1997-2013 or 1997-2015) and minimum landings thresholds (10,000 lb (4,536 kg), 25,000 lb (11,340 kg), or 50,000 lb (22,680 kg)). Of these five alternatives, only Alternative 1B is considered a significant alternative because it meets the objectives of this action and minimizes adverse economic impacts compared to the proposed action (Alternative 1C); the no action alternative (Alternative 1A) would not meet the objectives of this action.
Unlike the proposed action which is based on landings through 2013, Alternative 1B would re-qualify a vessel for a longfin squid moratorium permit if it landed more than 10,000 lb (4,536 kg) of longfin squid in any year during 1997-2015. Based on these criteria, 224 vessel permits currently issued a longfin squid/butterfish moratorium permit would qualify for and be issued a Tier 1 longfin squid moratorium permit under Amendment 20. The 159 vessels that would not qualify would be issued a Tier 2 longfin squid moratorium permit and be restricted to 5,000 lb (2,268 kg) of longfin squid per trip. From 2014-2016, 80 percent of these vessels (127) did not land any longfin squid. Of the 32 vessels that landed some longfin squid during 2014 and 2016, 6 vessels took 32 trips that landed more than 5,000 lb (2,268 kg) of longfin squid, all during 2016. If such trips would have been limited to 5,000 lb (2,268 kg) of longfin squid, foregone revenues would have totaled $438,835, or $73,139 annually per vessel. This amount represents 7 percent of their total average annual fishing revenues of $1,042,770 during 2014-2016. Given the increased availability of longfin squid during 2016, this is likely an upper bound estimate of the likely impacts to affected vessels, as availability fluctuates yearly and these vessels did not land more than 5,000 lb (2,268 kg) of longfin squid from any trip during 2014 or 2015.
Alternative 1B was not selected by the Council for several reasons. The year range used to requalify permits under this alternative (1997-2015) is not consistent with the May 16, 2013, control date specified by the Council for this action. This control date served as
Under Amendment 20, the Council considered three alternatives to reduce incidental catch permits in the longfin squid fishery, including the no-action alternative. Of these three alternatives, only Alternative 3B is considered a significant alternative because it meets the objectives of this action and minimizes adverse economic impacts compared to the preferred alternative (Alternative 3C); the no action alternative (Alternative 3A) would not meet the objectives of this action. Both Alternatives 3B and 3C used the same qualifying years (1997-2013), but different minimum landings thresholds (2,500 lb (1,134 kg) for Alternative 3B and 5,000 lb (2,268 kg) for Alternative 3C). Under each alternative, the Council considered two options for incidental longfin squid possession limits—250 lb (113 kg) or 500 lb (227 kg) per trip.
Under Alternative 3B, 385 vessels would qualify and be issued a Tier 3 longfin squid moratorium permit, allowing such vessels to continue landing up to 2,500 lb (1,134 kg) of longfin squid per trip. Out of the 1,143 vessels that would not qualify for a Tier 3 permit under Alternative 3B, 755 (66 percent) did not have any longfin squid landings during the qualifying period, while 388 (34 percent) landed less than 2,500 lb (1,134 kg) of longfin squid during the qualification period. Of these 388 permits with minimal longfin squid landings, 32 permits took 101 trips during 2014-2016 that landed 250-2,500 lb (113-1,134 kg) of longfin squid, resulting in nearly $270,000 in longfin squid revenue that averaged $1,120 per year for each permit. Twenty-one of these vessels took 52 trips during 2014-2016 that landed between 500-2,500 lb (226-1,134 kg) of longfin squid, averaging $1,437 per permit per year. Under either trip limit option, each non-qualified vessel would lose, on average, $1,134-$1,437 per year under Alternative 3B. These vessels earned an average of $683,723 from the landings of all species during 2014-2016. Therefore, longfin squid landings from trips affected by Alternative 3B represented only a small fraction (less than one quarter of one percent) of total fishing revenue for these vessels.
The Council selected Alternative 3C over Alternative 3B because the preferred alternative would more effectively create a system where vessels with incidental permits that had substantial longfin squid landings would keep their current possession limit and not be forced to discard longfin squid. It would also limit vessels without a history of substantial landings to a smaller possession limit. The higher minimum landing threshold under Alternative 3C would only require vessels to have made two trips maximizing the current incidental catch limit to qualify compared to one trip under Alternative 3B. This very low qualification threshold minimizes the number of non-qualified vessels to those that were landing minimal amounts of longfin squid in the past, consistent with the Council's rationale for selecting a low, but not the lowest, landings threshold to retain the longfin squid moratorium permit described above. Input from the Council's Mackerel, Squid, and Butterfish Advisory Panel indicated that a low possession limit of 250-500 lb (226-452 kg) would strongly reduce incentives to target longfin squid. Consistent with the objectives of this action, the Council preferred the lowest possession limit for incidental permits to eliminate incentives to target longfin squid and to minimize discards of squid caught as bycatch in other fisheries.
Under Amendment 20, the Council considered three alternatives to reduce the longfin squid incidental possession limit for all longfin squid permits once the available Trimester II quota was landed, including the no-action alternative. The no action alternative (Alternative 5A) would allow all permitted longfin squid vessels to continue to possess up to 2,500 lb (1,134 kg) of longfin squid after the Trimester II quota is caught and the directed fishery is closed, while Alternative 5B (the Council's preferred alternative) and 5C would allow vessels to retain up to 250 lb (113 kg) or 500 lb (226 kg) per trip, respectively, after such a closure. Alternatives 5A and 5C are both considered significant alternatives because they meet the objectives of this action and minimize adverse economic impacts compared to the preferred alternative.
Longfin squid landings and revenue from 2016 provide a good indication of potential maximum economic impacts to vessels under Alternatives 5A, 5B, and 5C, as longfin squid landings continued after the Trimester II directed fishery was closed from June 29-August 31, 2016. Assuming squid are similarly available in the future, 2016 landings data indicate that Alternative 5A could allow the fishery to land up to 5.6 million lb (2,540 mt) of longfin squid under the current 2,500 lb (1,134 kg) incidental possession limit following the closure of the directed fishery in Trimester II. Nearly all of these landings were from trips that landed more than 250 lb (113 kg), although not all landings occurred in Federal waters. Using 2016 prices, these landings were valued at $6.4 million, and represent an upper bound estimate of potential revenue under Alternative 5A that potentially would be lost under this action. Trips landing between 250-2,500 lb (113-1,134 kg) of longfin squid after the closure accounted for 3.4 million lb (1,542 mt) of longfin squid landings valued at $4.1 million. Average vessel revenue for the 129 vessels that took these trips was $31,444, representing just 4.8 percent of their total average longfin squid landing revenue ($649,473) during 2016. This approximates potential revenue losses under Alternative 5B. For a majority of these vessels, longfin squid was not a
The Council preferred Alternative 5B because it would better achieve the objectives of this action. Alternative 5B would provide additional control over longfin squid catch following the closure of the directed fishery during Trimester II and reduce negative impacts to longfin squid and egg mops during the spawning season. Landings after the 2016 Trimester II closure accounted for 30 percent of overall landings during that period. Excessive landings during Trimester II could negatively affect squid productivity and have been shown to reduce longfin squid catch rates in subsequent seasons. Unlike the no action alternative (Alternative 5A) and Alternative 5C, the preferred alternative would help prevent excessive longfin catch by reducing incentives to target longfin squid under a very low incidental possession limit based on input from the Council's Advisory Panel. During 2016, only one percent of longfin squid landings after the Trimester II closure occurred on trips landing 250 lb (113 kg) or less, suggesting that the proposed action would essentially eliminate excessive catch and more effectively ensure that landings do not exceed allowable limits during Trimester II. Although Alternative 5B would result in the highest potential foregone revenues among alternatives considered, if longfin squid remain available into Trimester III or future longfin squid productivity increases due to reduced effort during the spawning season, the preferred alternative may produce higher future economic returns than other alternatives.
Fisheries, Fishing, Recordkeeping and reporting requirements.
For the reasons set out in the preamble, 50 CFR part 648 is proposed to be amended as follows:
16 U.S.C. 1801
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(1) Federally permitted dealers, and any individual acting in the capacity of a dealer, must submit to the Regional Administrator or to the official designee a detailed report of all fish purchased or received for a commercial purpose, other than solely for transport on land, within the time period specified in paragraph (f) of this section, by one of the available electronic reporting mechanisms approved by NMFS, unless otherwise directed by the Regional Administrator. The dealer reporting requirements specified in this paragraph (a)(1) for dealers purchasing or receiving for a commercial purpose Atlantic chub mackerel are effective through December 31, 2020. The following information, and any other information required by the Regional Administrator, must be provided in each report:
(i)
(ii)
(A) Inshore Exempted Species, as defined in § 648.2, are not required to be reported under this part;
(B) When purchasing or receiving fish from a vessel landing in a port located outside of the Greater Atlantic Region (Maine, New Hampshire, Massachusetts, Connecticut, Rhode Island, New York, New Jersey, Pennsylvania, Maryland, Delaware, Virginia and North Carolina), only purchases or receipts of species managed by the Greater Atlantic Region under this part, and American lobster, managed under part 697 of this chapter, must be reported. Other reporting requirements may apply to those species not managed by the Northeast Region, which are not affected by this provision; and
(C) Dealers issued a permit for Atlantic bluefin tuna under part 635 of this chapter are not required to report their purchases or receipts of Atlantic bluefin tuna under this part. Other reporting requirements, as specified in § 635.5 of this chapter, apply to the receipt of Atlantic bluefin tuna.
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(i) For any vessel not issued a NE multispecies; Atlantic herring permit; or any Atlantic mackerel, longfin squid,
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(9) A vessel issued a Tier 1, Tier 2, or Tier 3 limited access Atlantic mackerel permit;
(10) A vessel issued a Tier 1 or Tier 2 longfin squid moratorium permit;
(11) A vessel issued an
(12) A vessel issued a butterfish moratorium permit.
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(i) A vessel subject to the VMS requirements of § 648.9 and paragraphs (b) through (d) of this section that has crossed the VMS Demarcation Line under paragraph (a) of this section is deemed to be fishing under the DAS program, the Access Area Program, the LAGC IFQ or NGOM scallop fishery, or other fishery requiring the operation of VMS as applicable, unless prior to leaving port, the vessel's owner or authorized representative declares the vessel out of the scallop, NE multispecies, monkfish, or any other fishery, as applicable, for a specific time period. NMFS must be notified by transmitting the appropriate VMS code through the VMS, or unless the vessel's owner or authorized representative declares the vessel will be fishing in the Eastern U.S./Canada Area, as described in § 648.85(a)(3)(ii), under the provisions of that program.
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(i) No vessel issued a limited access Atlantic mackerel permit or a longfin squid or butterfish moratorium permit may slip catch, as defined at § 648.2, except in the following circumstances:
(A) The vessel operator has determined, and the preponderance of available evidence indicates that, there is a compelling safety reason; or
(B) A mechanical failure, including gear damage, precludes bringing some or all of the catch on board the vessel for sampling and inspection; or
(C) The vessel operator determines that pumping becomes impossible as a result of spiny dogfish clogging the pump intake. The vessel operator shall take reasonable measures, such as strapping and splitting the net, to remove all fish that can be pumped from the net prior to release.
(ii) If a vessel issued any limited access Atlantic mackerel permit slips catch, the vessel operator must report the slippage event on the Atlantic mackerel and longfin squid daily VMS catch report and indicate the reason for slipping catch. Additionally, for a vessel issued a limited Atlantic mackerel permit or a longfin squid or butterfish moratorium permit, the vessel operator must complete and sign a Released Catch Affidavit detailing: The vessel name and permit number; the VTR serial number; where, when, and the reason for slipping catch; the estimated weight of each species brought on board or slipped on that tow. A completed affidavit must be submitted to NMFS within 48 hr of the end of the trip.
(a) Vessels issued a longfin squid, butterfish, or
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(A) Possess more than the incidental catch allowance of longfin squid, unless issued a longfin squid moratorium permit.
(D) Take and retain, possess, or land mackerel, squid, or butterfish in excess of a possession limit specified in § 648.26.
(F) Take and retain, possess, or land mackerel after a total closure specified under § 648.24(b)(1).
(H) Possess more than the incidental catch allowance of butterfish, unless issued a butterfish moratorium permit.
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(A) Fish with or possess nets or netting that do not meet the gear requirements for Atlantic mackerel, longfin squid,
(v) VMS r
(A) Fail to declare via VMS into the directed mackerel, longfin squid,, or
(vi) Slip catch, as defined at § 648.2, unless for one of the reasons specified
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(i) IOY, including RSA, DAH, and DAP for longfin squid, which, subject to annual review, may be specified for a period of up to 3 years; and
(ii) Inseason adjustment, upward or downward, to the specifications for longfin squid, as specified in paragraph (e) of this section.
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(3) The amount of longfin squid,
(6) Commercial seasonal quotas/closures for longfin squid and
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(i) If NMFS concurs with the MAFMC's recommended management measures and determines that the recommended management measures should be issued as a final rule based on the factors specified in paragraph (a)(3) of this section, the measures will be issued as a final rule in the
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(iii) Tier 3 moratorium permits. A vessel issued a Tier 3 longfin squid moratorium permit may not fish for, possess, or land more than 2,500 lb (1,134 kg) of longfin squid per trip, and may only land longfin squid once on any calendar day.
(2)
(i) A vessel issued an open access squid/butterfish incidental catch permit may not fish for, possess, or land more than 250 lb (113 kg) of longfin squid from or in the EEZ per trip, and may only land longfin squid once on any calendar day.
(ii) During a closure of the directed longfin squid fishery in either Trimester I or III pursuant to paragraph § 648.24(a)(1), a vessel may not fish for, possess, or land more than 2,500 lb (1,134 kg) of longfin squid at any time per trip, and may only land longfin squid once on any calendar day.
(iii) Unless otherwise specified in paragraph (b)(2)(iv) of this section, during a closure of the directed longfin squid fishery in Trimester II pursuant to § 648.24(a)(1), a vessel may not fish for, possess, or land more than 250 lb (113 kg) of longfin squid at any time per trip, and may only land longfin squid once on any calendar day.
(iv) During a closure of the directed longfin squid fishery in Trimester II, a vessel issued either a Tier 1 or Tier 2 longfin squid moratorium permit may possess more than 250 lb (113 kg) of longfin squid per trip, provided the following conditions are met:
(A) The vessel operator has declared into the directed
(B) The vessel is seaward of the coordinates specified at § 648.23(a)(5);
(C) The vessel possesses more than 10,000 lb (4,536 kg) of
(D) The vessel possesses less than 15,000 lb (6,803 kg) of longfin squid if issued a Tier 1 longfin squid moratorium permit or 5,000 lb (2,268 kg) of longfin squid if issued a Tier 2 longfin squid moratorium permit; and
(E) All fishing gear is stowed and rendered not available for immediate use, as defined in § 648.2, once the vessel is landward of the coordinates specified at § 648.23(a)(5).
(c)
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(2)
(i) A vessel is issued an open access squid/butterfish incidental catch permit; or
(ii) A vessel is issued an
(d)
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(ii)
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Animal and Plant Health Inspection Service, USDA.
Notice.
We are advising the public of our decision to concur with the World Organization for Animal Health's (OIE) bovine spongiform encephalopathy (BSE) risk designations for four regions. The OIE recognizes these regions as being of negligible risk for BSE. We are taking this action based on our review of information supporting the OIE's risk designations for these regions.
Dr. Rebecca Gordon, Senior Staff Veterinarian, Regionalization Evaluation Services, National Import Export Services, VS, APHIS, 920 Main Campus Drive, Suite 200, Raleigh, NC 27606; (919) 855-7741.
The regulations in 9 CFR part 92 subpart B, “Importation of Animals and Animal Products; Procedures for Requesting BSE Risk Status Classification With Regard To Bovines” (referred to below as the regulations), set forth the process by which the Animal and Plant Health Inspection Service (APHIS) classifies regions for bovine spongiform encephalopathy (BSE) risk. Section 92.5 of the regulations provides that all countries of the world are considered by APHIS to be in one of three BSE risk categories: Negligible risk, controlled risk, or undetermined risk. These risk categories are defined in § 92.1. Any region that is not classified by APHIS as presenting either negligible risk or controlled risk for BSE is considered to present an undetermined risk. The list of those regions classified by APHIS as having either negligible risk or controlled risk can be accessed on the APHIS website at
Under the regulations, APHIS may classify a region for BSE in one of two ways. One way is for regions that have not received a risk classification from the World Organization for Animal Health (OIE) to request classification by APHIS. The other way is for APHIS to concur with the classification given to a country or region by the OIE.
If the OIE has recognized a country as either BSE negligible risk or BSE controlled risk, APHIS will seek information to support our concurrence with the OIE classification. This information may be publicly available information, or APHIS may request that countries supply the same information given to the OIE. APHIS will announce in the
In accordance with that process, we published a notice
The commenter voiced doubts about the efficacy of the BSE minimal risk region policy, concerns about other prion diseases such as chronic wasting disease circulating in the United States and the world, and skepticism that the ruminant-to-ruminant feed ban has been effectively enforced. The commenter did not, however, address our preliminary concurrence with the OIE's risk designations for the four regions or the documentation made available to support that action.
Therefore, in accordance with the regulations in § 92.5, we are announcing our decision to concur with the OIE risk classifications of the following countries:
•
7 U.S.C. 1622 and 8301-8317; 21 U.S.C. 136 and 136a; 31 U.S.C. 9701; 7 CFR 2.22, 2.80, and 371.4.
National Agricultural Statistics Service, USDA.
Notice and request for comments.
In accordance with the Paperwork Reduction Act of 1995 this notice announces the intention of the National Agricultural Statistics Service (NASS) to request revision and extension of a currently approved information collection, the Stocks Reports. Revision to burden hours will be needed due to changes in the size of the target population, sampling design, and/or questionnaire length.
Comments on this notice must be received by October 30, 2018 to be assured of consideration.
You may submit comments, identified by docket number 0535-0007, by any of the following methods:
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•
•
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Kevin L. Barnes, Associate Administrator, National Agricultural Statistics Service, U.S. Department of Agriculture, (202) 720-2707. Copies of this information collection and related instructions can be obtained without charge from David Hancock, NASS—OMB Clearance Officer, at (202) 690-2388 or at
The current expiration date for this docket is January 31, 2019. NASS intends to request that the survey be approved for another 3 years.
NASS also complies with OMB Implementation Guidance, “Implementation Guidance for Title V of the E-Government Act, Confidential Information Protection and Statistical Efficiency Act of 2002 (CIPSEA),”
All responses to this notice will become a matter of public record and be summarized in the request for OMB approval.
National Agricultural Statistics Service, USDA.
Notice and request for comments.
In accordance with the Paperwork Reduction Act of 1995, this notice announces the intention of the National Agricultural Statistics Service (NASS) to request revision and extension of a currently approved information collection, the Egg, Chicken, and Turkey Surveys. A revision to burden hours will be needed due to changes in the size of the target population, sampling design, and/or questionnaire length.
Comments on this notice must be received by October 30, 2018 to be assured of consideration.
You may submit comments, identified by docket number 0535-0004, by any of the following methods:
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Kevin L. Barnes, Associate Administrator, National Agricultural Statistics Service, U.S. Department of Agriculture, (202) 720-2707. Copies of this information collection and related instructions can be obtained without charge from David Hancock, NASS—OMB Clearance Officer, at (202) 690-2388 or at
NASS also complies with OMB Implementation Guidance, “Implementation Guidance for Title V of the E-Government Act, Confidential Information Protection and Statistical Efficiency Act of 2002 (CIPSEA),”
All responses to this notice will become a matter of public record and be summarized in the request for OMB approval.
Rural Utilities Service, USDA.
Notice of Depreciation Rates for Telecommunications Plant.
The United States Department of Agriculture (USDA) Rural Utilities Service (RUS) administers rural utilities programs, including the Telecommunications Program. RUS announces the depreciation rates for telecommunications plant for the period ending December 31, 2017.
These rates are applicable immediately and will remain in effect until rates are available for the period ending December 31, 2018.
Chad Parker, Assistant Administrator, Telecommunications Program, Rural Utilities Service, STOP 1590—Room 5151, 1400 Independence Avenue SW, Washington, DC 20250-1590. Telephone: (202) 720-9556.
In 7 CFR part 1737, Pre-Loan Policies and Procedures Common to Insured and Guaranteed Telecommunications Loans, § 1737.70(e) explains the depreciation rates that are used by RUS in its feasibility studies. § 1737.70(e)(2) refers to median depreciation rates published by RUS for all borrowers. The following chart provides those rates, compiled by RUS, for the reporting period ending December 31, 2017:
Wednesday, September 5, 2018, 10:30 a.m. ET.
Cohen Building, Room 3321, 330 Independence Ave. SW, Washington, DC 20237.
This meeting will be open to the public.
The Broadcasting Board of Governors (Board) will be meeting at the time and location listed above. The Board will vote on a consent agenda consisting of the minutes of its June 6, 2018 meeting and a resolution honoring the 55th anniversary of Voice of America's English to Africa Service. The Board will receive a report from the Chief Executive Officer and Director of BBG.
This meeting will be available for public observation via streamed webcast, both live and on-demand, on the agency's public website at
The public may also attend this meeting in person at the address listed above as seating capacity permits. Members of the public seeking to attend the meeting in person must register at
Persons interested in obtaining more information should contact Oanh Tran at (202) 203-4545.
Department of Commerce.
Notice of membership on the Departmental Performance Review Board.
The Department of Commerce (DOC) announces the appointment of those individuals who have been selected to serve as members of the Departmental Performance Review Board. The Performance Review Board is responsible for reviewing performance appraisals and ratings of Senior Executive Service (SES) members and making recommendations to the appointing authority on other performance management issues, such as pay adjustments, bonuses and Presidential Rank Awards. The appointment of these members to the Performance Review Board will be for a period of twenty-four (24) months.
The period of appointment for those individuals selected for the Departmental Performance Review Board begins on August 31, 2018.
Christi Casiano, U.S. Department of Commerce, Office of Human Resources Management, Office of Executive Resources, 14th and Constitution Avenue NW, Room 51010, Washington, DC 20230, at (202) 482-0124.
In accordance with 5 U.S.C. 4314(c)(4), the Department of Commerce (DOC), announces the appointment of those individuals who have been selected to serve as members of the Departmental Performance Review Board. The Performance Review Board is responsible for (1) reviewing performance appraisals and ratings of Senior Executive Service (SES) members and (2) making recommendations to the appointing authority on other performance management issues, such as pay adjustments, bonuses and Presidential Rank Awards. The appointment of these members to the Performance Review Board will be for a period of twenty-four (24) months.
The name, position title, and type of appointment of each member of the Performance Review Board are set forth below:
An application has been submitted to the Foreign-Trade Zones (FTZ) Board by the Koochiching Economic Development Authority, grantee of FTZ 259, requesting subzone status for the facilities of Digi-Key Corporation, located in Thief River Falls, Minnesota. 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 FTZ Board (15 CFR part 400). It was formally docketed on August 24, 2018.
The proposed subzone would consist of the following sites:
In accordance with the FTZ Board's regulations, Elizabeth Whiteman 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 FTZ Board's Executive Secretary at the address below. The closing period for their receipt is October 10, 2018. Rebuttal comments in response to material submitted during the foregoing period may be submitted during the subsequent 15-day period to October 25, 2018.
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 FTZ Board's website, which is accessible via
For further information, contact Elizabeth Whiteman at
The Transportation and Related Equipment Technical Advisory Committee will meet on September 26, 2018, 9:30 a.m., in the Herbert C. Hoover Building, Room 3884, 14th Street between Constitution & Pennsylvania Avenues NW, Washington, DC. The Committee advises the Office of the Assistant Secretary for Export Administration with respect to technical questions that affect the level of export controls applicable to transportation and related equipment or technology.
1. Welcome and Introductions.
2. Status reports by working group chairs.
3. Public comments and Proposals.
4. Discussion of matters determined to be exempt from the provisions relating to public meetings found in 5 U.S.C. app. 2 §§ 10(a)(1) and 10(a)(3).
The open session will be accessible via teleconference to 20 participants on a first come, first serve basis. To join the conference, submit inquiries to Ms. Yvette Springer at
A limited number of seats will be available during the public session of the meeting. Reservations are not accepted. To the extent time permits, members of the public may present oral statements to the Committee. The public may submit written statements at any time before or after the meeting. However, to facilitate distribution of public presentation materials to Committee members, the Committee suggests that presenters forward the public presentation materials prior to the meeting to Ms. Springer via email.
The Assistant Secretary for Administration, with the concurrence of the delegate of the General Counsel, formally determined on August 24, 2018, pursuant to Section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. app. 2 § (10)(d)), that the portion of the meeting dealing with pre-decisional changes to the Commerce Control List and U.S. export control policies shall be exempt from the provisions relating to public meetings found in 5 U.S.C. app. 2 §§ 10(a)(1) and 10(a)(3). The remaining portions of the meeting will be open to the public.
For more information, call Yvette Springer at (202) 482-2813.
Enforcement and Compliance, International Trade Administration, Department of Commerce.
Based on affirmative final determinations by the Department of Commerce (Commerce) and the International Trade Commission (ITC), Commerce is issuing a countervailing duty order on cast iron soil pipe fittings (soil pipe fittings) from the People's Republic of China (China).
Applicable August 31, 2018.
Dennis McClure or Jinny Ahn, AD/CVD Operations, Office VIII, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 1401 Constitution Avenue NW, Washington, DC 20230; telephone (202) 482-5973 or (202) 482-0339, respectively.
On July 11, 2018, Commerce published its final determination in the countervailing duty investigation of soil pipe fittings from China.
The merchandise covered by the scope of this order is cast iron soil pipe fittings, finished and unfinished, regardless of industry or proprietary specifications, and regardless of size. Cast iron soil pipe fittings are nonmalleable iron castings of various designs and sizes, including, but not limited to, bends, tees, wyes, traps, drains (other than drain bodies), and other common or special fittings, with or without side inlets.
Cast iron soil pipe fittings are classified into two major types—hubless and hub and spigot. Hubless cast iron soil pipe fittings are manufactured without a hub, generally in compliance with Cast Iron Soil Pipe Institute (CISPI) specification 301 and/or American Society for Testing and Materials (ASTM) specification A888. Hub and spigot pipe fittings have hubs into which the spigot (plain end) of the pipe or fitting is inserted. Cast iron soil pipe fittings are generally distinguished from other types of nonmalleable cast iron fittings by the manner in which they are connected to cast iron soil pipe and other fittings.
Excluded from this scope are all drain bodies. Drain bodies are normally classified in subheading 7326.90.86.88 of the Harmonized Tariff Schedule of the United States (HTSUS).
The cast iron soil pipe fittings subject to the scope of this order are normally classified in subheading 7307.11.0045 of the HTSUS: Cast fittings of nonmalleable cast iron for cast iron soil pipe. They may also be entered under HTSUS 7324.29.0000 and 7307.92.3010. The HTSUS subheadings and specifications are provided for convenience and customs purposes only; the written description of the scope of this order is dispositive.
On August 22, 2018, in accordance with section 705(d) of the Act, the ITC notified Commerce of its final determination in this investigation, in which it found that imports of cast iron soil pipe fittings are materially injuring a U.S. industry. Therefore, in accordance with section 705(c)(2) of the Act, we are publishing this countervailing duty order. In its determination, the ITC found two domestic like products covered by the scope of the investigation: Drain bodies and all other soil pipe fittings. The ITC made a negative determination with respect to drain bodies and an
The ITC found that drain bodies are a separate domestic like product. The Final ITC Report describes typical drain bodies as having only one side that connects to a pipe or fitting.
Because the ITC made a negative determination of material injury with respect to drain bodies, Commerce will direct CBP to terminate the suspension of liquidation for entries of drain bodies from China entered, or withdrawn from warehouse, and refund any cash deposits with respect to these entries.
Because the ITC determined that imports of all cast iron soil pipe fittings other than drain bodies from China are materially injuring a U.S. industry, all unliquidated entries of subject merchandise from China, entered or withdrawn from warehouse, are subject to the assessment of countervailing duties.
As a result of the ITC's final determination, in accordance with section 706(a) of the Act, Commerce will direct CBP to assess, upon further instruction by Commerce, countervailing duties on unliquidated entries of subject merchandise from China entered, or withdrawn from warehouse, for consumption on or after December 19, 2017, the date on which Commerce published its preliminary countervailing duty determination in the
In accordance with section 706 of the Act, Commerce will direct CBP to reinstitute the suspension of liquidation of subject merchandise (
This notice constitutes the countervailing duty order with respect to soil pipe fittings from China pursuant to section 706(a) of the Act. Interested parties may visit
This order is issued and published in accordance with section 706(a) of the Act and 19 CFR 351.211(b).
Enforcement and Compliance, International Trade Administration, Department of Commerce.
The Department of Commerce (Commerce) preliminarily determines that cast iron soil pipe from the People's Republic of China (China) was sold to the United States at less than fair value (LTFV) during the period of investigation (POI), July 1, 2017, through December 31, 2017.
Applicable August 31, 2018.
Javier Barrientos, AD/CVD Operations, Office V, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 1401 Constitution Avenue NW, Washington, DC 20230; telephone: (202) 482-2243.
This preliminary determination is made in accordance with section 733(b) of the Tariff Act of 1930, as amended (the Act). Commerce published the notice of initiation of this investigation on February 23, 2018.
For a complete description of the events that followed the initiation of this investigation,
The product covered by this investigation is cast iron soil pipe from China. For a complete description of the scope of this investigation,
In accordance with the preamble to Commerce's regulations,
Commerce is conducting this investigation in accordance with section 731 of the Act. Export price was calculated in accordance with sections 772(a) of the Act. Because China is a non-market economy within the meaning of section 771(18) of the Act, normal value was calculated in accordance with section 773(c) of the Act. Furthermore, pursuant to section 776(a) and (b) of the Act, we have preliminarily relied upon facts otherwise available, with adverse inferences, for Sibo International Ltd., and the China-wide entity. For a full description of the methodology underlying Commerce's preliminary determination,
In the
Commerce preliminarily determines that the following estimated weighted-average dumping margins exist:
In accordance with section 733(d)(2) of the Act, Commerce will direct U.S. Customs and Border Protection (CBP) to suspend liquidation of subject merchandise as described in the scope of the investigation section entered, or withdrawn from warehouse, for consumption on or after the date of publication of this notice in the
To determine the cash deposit rate, Commerce normally adjusts the estimated weighted-average dumping margin by the amount of domestic subsidy pass-through and export subsidies determined in a companion countervailing duty (CVD) proceeding when CVD provisional measures are in effect. Accordingly, where Commerce makes a preliminary affirmative determination for domestic subsidy pass-through or export subsidies, Commerce offsets the calculated estimated weighted-average dumping margin by the appropriate rate(s). In this case, we have not made a preliminary affirmative determination for domestic subsidy pass-through or export subsidies. Therefore, we are not adjusting the estimated weighted-average dumping margin for these subsidies.
These suspension of liquidation instructions will remain in effect until further notice.
Commerce intends to disclose to interested parties the calculations performed in connection with this preliminary determination within five days of its public announcement or, if there is no public announcement, within five days of the date of publication of this notice in accordance with 19 CFR 351.224(b).
As provided in section 782(i)(1) of the Act, Commerce intends to verify information relied upon in making its final determination.
Case briefs or other written comments may be submitted to the Assistant Secretary for Enforcement and Compliance no later than seven days after the date on which the last final verification report is issued in this investigation. Rebuttal briefs, limited to issues raised in case briefs, may be submitted no later than five days after the deadline date for case briefs.
Pursuant to 19 CFR 351.310(c), interested parties who wish to request a hearing, limited to issues raised in the case and rebuttal briefs, must submit a written request to the Assistant Secretary for Enforcement and Compliance, U.S. Department of Commerce, within 30 days after the date of publication of this notice. Requests should contain the party's name, address, and telephone number, the number of participants, whether any participant is a foreign national, and a list of the issues to be discussed. If a request for a hearing is made, Commerce intends to hold the hearing at the U.S. Department of Commerce, 1401 Constitution Avenue NW, Washington, DC 20230, at a time and date to be determined. Parties should confirm by telephone the date, time, and location of the hearing two days before the scheduled date.
Section 735(a)(2) of the Act provides that a final determination may be postponed until not later than 135 days after the date of the publication of the preliminary determination if, in the event of an affirmative preliminary determination, a request for such postponement is made by exporters who account for a significant proportion of exports of the subject merchandise, or in the event of a negative preliminary determination, a request for such postponement is made by the petitioner. Pursuant to 19 CFR 351.210(e)(2), Commerce requires that requests by respondents for postponement of a final antidumping determination be accompanied by a request for extension of provisional measures from a four-month period to a period not more than six months in duration.
On August 2, 2018, pursuant to 19 CFR 351.210 (e), HengTong requested that Commerce postpone the final determination and that provisional measures be extended to a period not to exceed six months.
In accordance with section 733(f) of the Act, Commerce will notify the International Trade Commission (ITC) of its preliminary determination of sales at LTFV. If the final determination is affirmative, the ITC will determine before the later of 120 days after the date of this preliminary determination or 45 days after the final determination whether imports of the subject merchandise are materially injuring, or threaten material injury to, the U.S. industry.
This determination is issued and published in accordance with sections 733(f) and 777(i)(1) of the Act and 19 CFR 351.205(c).
The merchandise covered by this investigation is cast iron soil pipe, whether finished or unfinished, regardless of industry or proprietary specifications, and regardless of wall thickness, length, diameter, surface finish, end finish, or stenciling. The scope of this investigation includes, but is not limited to, both hubless and hub and spigot cast iron soil pipe. Cast iron soil pipe is nonmalleable iron pipe of various designs and sizes. Cast iron soil pipe is generally distinguished from other types of nonmalleable cast iron pipe by the manner in which it is connected to cast iron soil pipe fittings.
Cast iron soil pipe is classified into two major types—hubless and hub and spigot. Hubless cast iron soil pipe is manufactured without a hub, generally in compliance with Cast Iron Soil Pipe Institute (CISPI) specification 301 and/or American Society for Testing and Materials (ASTM) specification A888, including any revisions to those specifications. Hub and spigot pipe has one or more hubs into which the spigot (plain end) of a fitting is inserted. All pipe meeting the physical description set forth above is covered by the scope of this investigation, whether or not produced according to a particular standard.
The subject imports are currently classified in subheading 7303.00.0030 of the Harmonized Tariff Schedule of the United States (HTSUS): Cast iron soil pipe. The HTSUS subheading and specifications are provided for convenience and customs purposes only; the written description of the scope of this investigation is dispositive.
Enforcement and Compliance, International Trade Administration, Department of Commerce.
The Department of Commerce (Commerce) is amending its final determination of sales at less than fair value (LTFV) as a result of ministerial errors. In addition, based on affirmative final determinations by Commerce and the International Trade Commission (the ITC), Commerce is issuing an antidumping duty order on cast iron soil pipe fittings (soil pipe fittings) from the People's Republic of China (China).
Applicable August 31, 2018.
Sergio Balbontin at (202) 482-4474 or Michael Bowen at (202) 482-0768, AD/CVD Operations, Enforcement and Compliance, U.S. Department of Commerce, 1401 Constitution Avenue NW, Washington, DC 20230.
On July 17, 2018, Commerce published its affirmative final determination in the LTFV investigation of soil pipe fittings from China on July 17, 2018.
On August 22, 2018, the ITC notified Commerce of its final determination, pursuant to 735(d) of the Act, that an industry in the United States is materially injured within the meaning of section 735(b)(1)(A)(i) of the Act, by reason of LTFV imports of soil pipe fittings from China, and of its determination that critical circumstances do not exist with respect to imports of soil pipe fittings from China.
The merchandise covered by the scope of this order is cast iron soil pipe fittings, finished and unfinished, regardless of industry or proprietary specifications, and regardless of size. Cast iron soil pipe fittings are nonmalleable iron castings of various designs and sizes, including, but not limited to, bends, tees, wyes, traps, drains (other than drain bodies), and other common or special fittings, with or without side inlets.
Cast iron soil pipe fittings are classified into two major types—hubless and hub and spigot. Hubless cast iron soil pipe fittings are manufactured without a hub, generally in compliance with Cast Iron Soil Pipe Institute (CISPI) specification 301 and/or American Society for Testing and Materials (ASTM) specification A888. Hub and spigot pipe fittings have hubs into which the spigot (plain end) of the pipe or fitting is inserted. Cast iron soil pipe fittings are generally distinguished from other types of nonmalleable cast iron fittings by the manner in which they are connected to cast iron soil pipe and other fittings.
Excluded from the scope are all drain bodies. Drain bodies are normally classified in subheading 7326.90.86.88 of the Harmonized Tariff Schedule of the United States (HTSUS).
The cast iron soil pipe fittings subject to the scope of this order are normally classified in subheading 7307.11.0045 of the HTSUS: Cast fittings of nonmalleable cast iron for cast iron soil pipe. They may also be entered under HTSUS 7324.29.0000 and 7307.92.3010. The HTSUS subheadings and specifications are provided for convenience and customs purposes only; the written description of the scope of this order is dispositive.
Pursuant to 19 CFR 351.224(e), Commerce is amending the
In addition, we are amending our instructions to U.S. Customs and Border Protection (CBP) with respect to the cash deposit rates in effect during certain periods of this LTFV investigation. Specifically, in the
Further, for the period of July 17, 2018, until the date of expiration of provisional measures in this LTFV investigation (August 20, 2018), the correct cash deposit rates shall be equal to the estimated weighted-average dumping margins calculated in the
For the purposes of this amended final determination and order, we will instruct CBP to resume collecting cash deposits equal to the estimated weighted-average dumping margins listed below, adjusted for the export subsidy rates imposed in the companion CVD investigation,
On August 22, 2018, in accordance with section 735(b)(1)(A)(i) and 735(d) of the Act, the ITC notified Commerce of its final determination in this investigation, in which it found that imports of cast iron soil pipe fittings are materially injuring a U.S. industry. Therefore, in accordance with section 735(c)(2) and 736(a) of the Act, we are publishing this antidumping duty order. In its determination, the ITC found two domestic like products covered by the scope of the investigation: drain bodies and all other soil pipe fittings. The ITC made a negative determination with respect to drain bodies and an affirmative determination with respect to all other soil pipe fittings. Because the ITC made different injury determinations for separate domestic like products, Commerce will instruct CBP to assess antidumping duties on entries of all cast iron soil pipe fittings (subject merchandise) other than drain bodies (excluded merchandise).
The ITC found that drain bodies are a separate domestic like product. The Final ITC Report describes typical drain bodies as having only one side that connects to a pipe or fitting.
Because the ITC made a negative determination of material injury with respect to drain bodies, Commerce will direct CBP to terminate the suspension of liquidation for entries of drain bodies from China entered, or withdrawn from warehouse, and refund any cash deposit with respect to these entries.
Because the ITC determined that imports of all cast iron soil pipe fittings other than drain bodies from China are materially injuring a U.S. industry, all unliquidated entries of subject merchandise from China, entered or withdrawn from warehouse, are subject to the assessment of antidumping duties.
As a result of the ITC's final determination, in accordance with section 736(a)(1) of the Act, Commerce will direct CBP to assess, upon further instruction by Commerce, antidumping duties equal to the amount by which the normal value of the merchandise exceeds the export price (or constructed export price) of the merchandise, for all relevant entries of soil pipe fittings from China. Antidumping duties will be assessed on unliquidated soil pipe fittings from China entered, or withdrawn from warehouse, for consumption on or after February 20, 2018, the date of publication of the
In accordance with section 735(c)(1)(B) of the Act, Commerce will direct CBP to continue to suspend liquidation of subject merchandise (
Accordingly, effective on the date of publication of the ITC's final affirmative injury determination, CBP will require, at the same time as importers would normally deposit estimated duties on this subject merchandise, a cash deposit equal to the estimated weighted-average dumping margins listed below.
Section 733(d) of the Act states that instructions issued pursuant to an affirmative preliminary determination may not remain in effect for more than four months, except where exporters representing a significant proportion of exports of the subject merchandise request Commerce to extend that four-month period to no more than six months. At the request of exporters that account for a significant proportion of soil pipe fittings from China, Commerce extended the four-month period to six months in this proceeding.
Therefore, in accordance with section 733(d) of the Act and our practice,
With regard to the ITC's negative critical circumstances determination on imports of soil pipe fittings from China discussed above, we will instruct CBP to lift suspension and to refund any cash deposits made to secure the payment of estimated antidumping duties with respect to entries of soil pipe fittings from China, entered or withdrawn from warehouse, for consumption on or after November 22, 2017 (
The estimated weighted-average dumping margins are as follows:
This notice constitutes the antidumping duty order with respect to soil pipe fittings from China pursuant to section 736(a) of the Act. Interested parties can find a list of antidumping duty orders currently in effect at
This amended final determination and antidumping duty order are published in accordance with sections 735(e) and 736(a) of the Act and 19 CFR 351.224(e) and 351.211(b).
Enforcement and Compliance, International Trade Administration, Department of Commerce.
The Department of Commerce (Commerce) preliminarily determines that countervailable subsidies are being provided to producers and exporters of certain steel wheels from the People's Republic of China (China) for the period of investigation January 1, 2017, through December 31, 2017. We invite interested parties to comment on this preliminary determination.
Applicable August 31, 2018.
Chien-Min Yang or Myrna Lobo, AD/CVD Operations, Office VII, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 1401 Constitution Avenue NW, Washington, DC 20230; telephone: 202-482-5484 or 202-482-2371, respectively.
This preliminary determination is made in accordance with section 703(b) of the Tariff Act of 1930, as amended (the Act). Commerce published the notice of initiation of this investigation on April 16, 2018.
For a complete description of the events that followed the initiation of this investigation, see the Preliminary Decision Memorandum.
The products covered by this investigation are certain steel wheels from China. For a complete description of the scope of this investigation,
In accordance with the Preamble to Commerce's regulations, we set aside a period of time in our
In accordance with section 705(a)(1) of the Act and 19 CFR 351.210(b)(4), and based on the petitioners' request,
Commerce is conducting this investigation in accordance with section 701 of the Act. For each of the subsidy programs found countervailable, Commerce preliminarily determines that there is a subsidy,
Commerce notes that, in making these findings, it relied, in part, on facts available and, because it finds that one or more respondents did not act to the best of their ability to respond to Commerce's requests for information, it drew an adverse inference where appropriate in selecting from among the facts otherwise available.
In accordance with section 705(c)(1)(B)(i)(I) of the Act, Commerce established rates for Xiamen Sunrise Wheel Group Co., Ltd. (Xiamen Sunrise), Xiamen Sunrise Wheel Co., Ltd. (Sunrise Wheel), Xiamen Sunrise Metal Co., Ltd. (Sunrise Metal), Xiamen Topu Import & Export Co., Ltd. (Topu), and Sichuan Sunrise Metal Industry Co., Ltd. (Sichuan Sunrise) (collectively, Xiamen Sunrise), and applied a rate based on adverse facts available to Zhejiang Jingu Company Limited and Shanghai Yata Industry Company Limited (collectively, Zhejiang Jingu).
In accordance with sections 705(d)(1)(A) and 705(c)(5)(A) of the Act, for companies not individually investigated, Commerce applies an “all-others” rate. The all-others rate is normally calculated by weight averaging the subsidy rates of the individual companies selected for individual examination with those companies' export sales of the subject merchandise to the United States, excluding any zero and
In this investigation, the only rates that are not zero or
Commerce preliminarily determines that the following estimated countervailable subsidy rates exist:
In
Commerce intends to disclose its calculations and analysis to interested parties in this preliminary determination within five days of its public announcement, or if there is no public announcement, within five days of the date of this notice in accordance with 19 CFR 351.224(b).
As provided in section 782(i)(1) of the Act, Commerce intends to verify the information relied upon in making its final determination.
Case briefs or other written comments may be submitted to the Assistant Secretary for Enforcement and Compliance no later than seven days after the date on which the last verification report is issued in this investigation. Rebuttal briefs, limited to issues raised in case briefs, may be submitted no later than five days after the deadline date for case briefs.
Pursuant to 19 CFR 351.310(c), interested parties who wish to request a hearing, limited to issues raised in the case and rebuttal briefs, must submit a written request to the Assistant Secretary for Enforcement and Compliance, U.S. Department of Commerce within 30 days after the date of publication of this notice. Requests should contain the party's name, address, and telephone number, the number of participants, whether any participant is a foreign national, and a list of the issues to be discussed. If a request for a hearing is made, Commerce intends to hold the hearing at the U.S. Department of Commerce, 1401 Constitution Avenue NW, Washington, DC 20230, at a time and date to be determined. Parties should confirm by telephone the date, time, and location of the hearing two days before the scheduled date.
Parties are reminded that briefs and hearing requests are to be filed electronically using ACCESS and that electronically filed documents must be received successfully in their entirety by 5 p.m. Eastern Time on the due date.
In accordance with section 703(f) of the Act, Commerce will notify the International Trade Commission (ITC) of its determination. If Commerce's final determination is affirmative, the ITC will make its final determination before the later of 120 days after the date of this preliminary determination or 45 days after Commerce's final determination.
This determination is issued and published pursuant to sections 703(f) and 777(i) of the Act and 19 CFR 351.205(c).
The merchandise subject to this investigation is certain on-the-road steel wheels, discs, and rims for tubeless tires, with a nominal rim diameter of 22.5 inches and 24.5 inches, regardless of width. Certain on-the-road steel wheels with a nominal wheel diameter of 22.5 inches and 24.5 inches are generally for Class 6, 7, and 8 commercial vehicles (as classified by the Federal Highway Administration Gross Vehicle Weight Rating system), including tractors, semi-trailers, dump trucks, garbage trucks, concrete mixers, and buses, and are the current standard wheel diameters for such applications. The standard widths of certain on-the-road steel wheels are 7.5 inches, 8.25 inches, and 9.0 inches, but all certain on-the-road steel wheels, regardless of width, are covered by the scope. While 22.5 inches and 24.5 inches are standard wheel sizes used by Class 6, 7, and 8 commercial vehicles, the scope covers sizes that may be adopted in the future for Class 6, 7, and 8 commercial vehicles.
The scope includes certain on-the-road steel wheels with either a “hub-piloted” or “stud- piloted” mounting configuration, and includes rims and discs for such wheels, whether imported as an assembly or separately. The scope includes certain on-the-road steel wheels, discs, and rims, of carbon and/or alloy steel composition, whether cladded or not cladded, whether finished or not finished, and whether coated or uncoated. All on-the-road wheels sold in the United States are subject to the requirements of the National Highway Traffic Safety Administration and bear markings, such as the “DOT” symbol, indicating compliance with applicable motor vehicle standards. See 49 CFR 571.120. The scope includes certain on- the-road steel wheels imported with or without the required markings. Certain on-the-road steel wheels imported as an assembly with a tire mounted on the wheel and/or with a valve stem attached are included. However, if the certain on-the-road steel wheel is imported as an assembly with a tire mounted on the wheel and/or with a valve stem attached, the certain on- the-road steel wheel is covered by the scope, but the tire and/or valve stem is not covered by the scope.
Excluded from the scope are:
(1) Steel wheels for tube-type tires that require a removable side ring;
(2) aluminum wheels;
(3) wheels where steel represents less than fifty percent of the product by weight; and
(4) steel wheels that do not meet National Highway Traffic Safety Administration requirements, other than the rim marking requirements found in 49 CFR 571.120S5.2.
Imports of the subject merchandise are currently classified under the following
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice; public meeting.
The New England Fishery Management Council (Council) is scheduling a public meeting of its Groundfish Committee to consider actions affecting New England fisheries in the exclusive economic zone (EEZ). Recommendations from this group will be brought to the full Council for formal consideration and action, if appropriate.
This meeting will be held on Tuesday, September 18, 2018 at 1:30 p.m.
Thomas A. Nies, Executive Director, New England Fishery Management Council; telephone: (978) 465-0492.
The committee will discuss Framework Adjustment 58: Specifications/Management Measures specifically draft alternatives and analysis including: (1) Rebuilding plan options for several groundfish stocks, (2) 2019 total allowable catches for U.S./Canada stocks of Eastern Georges Bank (GB) cod, Eastern GB haddock, and GB yellowtail flounder, (3) minimum size exemptions for vessels fishing in Northwest Atlantic Fisheries Organization waters, and (4) guidance on sector overages. They also plan to discuss Amendment 23, Groundfish Monitoring and receive an update on the development of the draft alternatives and analysis. The committee will review the Council's Groundfish Priorities for 2019 and discuss a draft list of possible groundfish priorities for 2019 and make recommendations to the Council. Review Groundfish Plan Development Team, Groundfish Advisory Panel, and Transboundary Management Guidance Committee recommendations and make recommendations to the Council. Other business will be discussed as necessary.
Although non-emergency issues not contained in this agenda may come before this group for discussion, those issues may not be the subject of formal action during these meetings. Action will be restricted to those issues specifically listed in this notice and any issues arising after publication of this notice that require emergency action under section 305(c) of the Magnuson-Stevens Act, provided the public has been notified of the Council's intent to take final action to address the emergency. This meeting will be recorded. Consistent with 16 U.S.C. 1852, a copy of the recording is available upon request.
This meeting is physically accessible to people with disabilities. Requests for sign language interpretation or other auxiliary aids should be directed to Thomas A. Nies, Executive Director, at (978) 465-0492, at least 5 days prior to the date.
16 U.S.C. 1801
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of scoping meetings.
The South Atlantic Fishery Management Council (Council) will hold a series of scoping meetings pertaining to Amendment 47 to the Snapper Grouper Fishery Management Plan of the South Atlantic Region addressing modifications to the South Atlantic Charter/Headboat for Snapper-Grouper permit.
The series of scoping meetings will be held from October 1 through November 1, 2018. All meetings will begin at 6 p.m.
See
Kim Iverson, Public Information Officer, SAFMC; phone: (843) 571-4366 or toll free: (866) SAFMC-10; fax: (843) 769-4520; email:
Public scoping comments are being solicited for measures proposed in draft Amendment 47 to the Snapper Grouper Fishery Management Plan of the South Atlantic Region addressing modifications to the federal South Atlantic Charter/Headboat for Snapper-Grouper permit (for-hire permit). Public scoping occurs early in the amendment development process and the Council is soliciting input on proposed options that include a moratorium on for-hire permits, options for the start date of a moratorium, exceptions for eligibility, transferability of for-hire permits, options to allow new entrants, establishing a for-hire permits pool, creating multiple for-hire permit types, and implementing a time limit or sunset
Council staff will provide an overview of options being considered for draft Snapper Grouper Amendment 47 and answer questions during each scoping meeting. Public comments will be accepted at each scoping meeting location on the specified date.
The Council requests that written comments be submitted using the online public comment form available from the Council's website. All comments submitted using the online form will be automatically posted to the website and accessible for Council members and the public to view. The direct link to the Public Hearing and Scoping meeting page and the public comment form is:
Comments may be submitted by mail to: Gregg Waugh, Executive Director, SAFMC, 4055 Faber Place Drive, Suite 201, North Charleston, SC 29405. Fax comments to 843/769-4520.
The Snapper Grouper Amendment 47 scoping document, public comment form, and other relevant materials will be posted on the Council's website as they become available.
These meetings are physically accessible to people with disabilities. Requests for auxiliary aids should be directed to the council office (see
The times and sequence specified in this agenda are subject to change.
16 U.S.C. 1801
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of public meeting.
The North Pacific Fishery Management Council (Council) Fishery Monitoring Advisory Committee will meet September 13, 2018 through September 14, 2018.
The meeting will be held on Thursday, September 13, 2018, from 9 a.m. to 5:30 p.m. and on Friday, September 14, 2018, from 9 a.m. to 3 p.m. (or as needed).
The meeting will be held in Room 2039, Building 4, at the Alaska Fisheries Science Center, 7600 Sand Point Way NE, Seattle, WA 98115; Teleconference number: (907) 271-2896.
Elizabeth Figus, Council staff; telephone: (907) 271-2809.
The agenda will include: A discussion of EM updates (including latest developments from the trawl EM Committee), presentation of the draft Annual Deployment Plan, a review of the NMFS Observer Safety Document, and a discussion of observer analyses.
The Agenda is subject to change, and the latest version will be posted at
Public comment letters will be accepted and should be submitted either electronically to Elizabeth Figus, Council staff:
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.
National Marine Fisheries Service (NMFS), National Oceanic and
Meeting of the South Atlantic Fishery Management Council.
The South Atlantic Fishery Management Council (Council) will hold meetings of the following: Advisory Panel Selection Committee (Closed Session); Southeast Data, Assessment and Review (SEDAR) Committee; Standard Operating, Policy, and Procedure (SOPPs) Committee; Spiny Lobster Committee; Habitat Protection and Ecosystem-Based Management Committee; Snapper Grouper Committee; Mackerel Cobia Committee; and Executive Finance Committee. The Council meeting week will also include a Recreational Fishing Workshop, a formal public comment period, and a meeting of the full Council.
The Council meeting will be held from 1 p.m. on Sunday, September 16, 2018 until 12 p.m. on Friday, September 21, 2018.
The meeting will be held at the Town and Country Inn, 2008 Savannah Highway, Charleston, SC phone: (843) 571-1000; fax: (843) 766-9444.
Kim Iverson, Public Information Officer, SAFMC; phone: (843) 571-4366 or toll free: (866) SAFMC-10; fax: (843) 769-4520; email:
The items of discussion in the individual meeting agendas are as follows:
The Council is cooperating with the American Sportfishing Association (ASA), Coastal Conservation Association (CCA), and Yamaha Marine Group to conduct a Recreational Workshop prior to the Council meeting. The September workshop is part of a 3-phrase project to explore approaches to innovative management of the private recreational sector of the South Atlantic Snapper Grouper fishery. Participants include Council members and Snapper Grouper advisory panel representatives, and other invited representatives identified by ASA from the recreational fishing community that are familiar with the Council process and recreational fishing issues. The public is welcome to attend and listen to the workshop and subsequent regional meetings. Comments on the September workshop may be provided during the Council meeting public comment session scheduled for Wednesday, September 19, 2018 at 4 p.m.
Newly appointed Council members will be sworn to duty by the NOAA Fisheries Regional Administrator.
1. The Committee will review applications for open seats on its System Management Plan Workgroup and advisory panels and provide recommendations for appointments.
2. The Committee will also discuss improving communication with advisory panels and provide direction to staff.
The Committee will receive an update on stock assessment activities including an overview of projects, Steering Committee actions, discuss items for the next Steering Committee meeting, and provide guidance to staff as needed.
The Committee will review and approve proposed changes to the Council Handbook and develop recommendations as appropriate.
1. The Committee will receive an update on the status of 2017-2018 catches versus annual catch limit (ACLs) and an update from NOAA Fisheries on the status of amendments under formal review.
2. The Committee will review Spiny Lobster Amendment 13 addressing bullynets and measures recommended by the Florida Fish and Wildlife Conservation Commission (FWC), consider public comment, and consider approval for formal Secretarial review.
1. The Committee will discuss ways to address species migration northwards along the Atlantic Coast, with input from the New England Fishery Management Council, the Mid-Atlantic Fishery Management Council, and the South Atlantic Fishery Management Council. The committee will provide guidance and take action as appropriate.
2. The committee will receive an update on the Fishery Ecosystem Plan II Dashboard and tools, an overview of NOAA Fisheries Ecosystem-Based Fishery Management Implementation Plan draft for the South Atlantic Region, and take action as needed.
1. The committee will receive updates from NOAA fisheries on commercial catches versus quotas for species under ACLS and the status of amendments under formal secretarial review.
2. The Committee will review public scoping comments received for Snapper Grouper Regulatory Amendment 29 addressing best practices and options for use of powerhead gear and approve actions and alternatives to be analyzed as appropriate.
3. The Committee will receive an overview of Vision Blueprint Regulatory Amendment 26 addressing recreational management actions and alternatives as identified in the 2016-2020 Vision Blueprint for the Snapper Grouper Fishery Management Plan. The
4. The Committee will receive an overview of Vision Blueprint Regulatory Amendment 27 addressing commercial management actions and alternatives, as identified in the 2016-2020 Vision Blueprint for the Snapper Grouper Fishery. The Committee will modify the document as necessary and consider approval for formal Secretarial review.
5. The Committee will review public scoping comments for Snapper Grouper Amendment 47 addressing federal for-hire permit modification options and provide guidance to staff.
6. The Committee will receive an overview of Regulatory Amendment 30 addressing a rebuilding plan for red grouper, modify the draft amendment as necessary and approve preferred alternatives.
7. The Committee will review public scoping comments for Snapper Grouper Regulatory Amendment 32 addressing yellowtail snapper accountability measures, review the draft amendment, modify actions, and consider approval for public hearings.
8. The Committee will review Abbreviated Framework Amendment 2 addressing measures for vermilion snapper and black sea bass, modify the draft amendment as necessary, choose preferred alternatives, and consider approval for formal Secretarial review.
1. The Committee will receive an update on commercial catches versus ACLs, and an update on the status of amendments under formal review by NOAA Fisheries.
2. The Committee will review Coastal Migratory Pelagics Framework Amendment 6 addressing Atlantic king mackerel trip limits, confirm preferred alternatives, and consider approval for formal Secretarial Review.
Public comment will be accepted on items on the Council meeting agenda scheduled to be approved for Secretarial Review: Snapper Grouper Abbreviated Framework 2 Amendment (vermilion snapper and black sea bass); Snapper Grouper Vision Blueprint Regulatory Amendment 27 (commercial measures); CMP Framework Amendment 6 (King mackerel trip limits); and Spiny Lobster Amendment 13 (Update management procedures and bully net measures). Public comment will also be accepted on all agenda items. The Council Chair, based on the number of individuals wishing to comment, will determine the amount of time provided to each commenter.
1. The Committee will receive an overview of the current Magnuson-Stevens Reauthorization efforts and the CCC Working Paper which includes positions on reauthorization, discuss, and provide guidance to staff.
2. The Committee will receive an overview of the draft Calendar-Year 2018 budget and approve the budget.
3. The committee will review the Council's Follow Up document and Priorities list, discuss, and provide guidance to staff.
4. The Committee will receive an update on regulatory reform efforts, a review of NOAA Fisheries issues open for comment, and an overview of the Law Enforcement Advisory Panel meeting schedule. The committee will discuss these agenda items and provide guidance to staff.
The Full Council will begin with the Call to Order, adoption of the agenda, approval of minutes, election of chair and vice chair, and awards/recognition.
The Council will receive a Legal Briefing on Litigation from NOAA General Counsel (if needed) during Closed Session. The Council will receive staff reports including the Executive Director's Report, and updates from Council staff on the MyFishCount pilot project, outreach for for-hire electronic reporting requirements, the Council's Citizen Science Program, and the transition to an electronic newsletter.
Updates will be provided by NOAA Fisheries including a report on the status of commercial catches versus ACLs for species not covered during an earlier committee meeting, data-related reports, protected resources updates, update on the status of the of the Commercial Electronic Logbook Program, and the status of the Marine Recreational Information Program (MRIP) conversions for recreational fishing estimates. The Council will discuss and take action as necessary.
The Council will review any Exempted Fishing Permits received as necessary. The Council will receive an overview of MRIP and Revisions from NOAA Fisheries as well as Draft Amendment 11 to the 2006 Consolidated Atlantic Highly Migratory Species Fishery Management Plan for Management of Shortfin Mako Sharks and take action as appropriate.
The Council will receive committee reports from the Snapper Grouper, Mackerel Cobia, Spiny Lobster, AP Selection, SEDAR, Habitat, SOPPs, and Executive Finance Committees, as well a report from the Recreational Workshop, and take action as appropriate.
The Council will receive agency and liaison reports; and discuss other business and upcoming meetings.
Documents regarding these issues are available from the Council office (see
Although non-emergency issues not contained in this agenda may come before this group for discussion, those issues may not be the subject of formal action during this meeting. Action will be restricted to those issues specifically identified in this notice and any issues arising after publication of this notice that require emergency action under section 305(c) of the Magnuson-Stevens Fishery Conservation and Management Act, provided the public has been notified of the Council's intent to take final action to address the emergency.
These meetings are physically accessible to people with disabilities. Requests for auxiliary aids should be directed to the Council office (see
The times and sequence specified in this agenda are subject to change.
16 U.S.C. 1801
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice; issuance of an incidental harassment authorization.
In accordance with the regulations implementing the Marine Mammal Protection Act (MMPA), as amended, notification is hereby given that NMFS has issued an incidental harassment authorization (IHA) to Lamont-Doherty Earth Observatory of Columbia University (L-DEO) to incidentally take, by Level A and/or Level B harassment, marine mammals during a Marine Geophysical Survey in the North Pacific Ocean.
This Authorization is effective from September 1, 2018, through August 31, 2019.
Rob Pauline, Office of Protected Resources, NMFS, (301) 427-8401. Electronic copies of the application and supporting documents, as well as a list of the references cited in this document, may be obtained online at:
The MMPA prohibits the “take” of marine mammals, with certain exceptions. Sections 101(a)(5)(A) and (D) of the MMPA (16 U.S.C. 1361
Authorization for incidental takings shall be granted if NMFS finds that the taking will have a negligible impact on the species or stock(s) and will not have an unmitigable adverse impact on the availability of the species or stock(s) for taking for subsistence uses (where relevant). Further, NMFS must prescribe the permissible methods of taking and other “means of effecting the least practicable [adverse] impact” on the affected species or stocks and their habitat, paying particular attention to rookeries, mating grounds, and areas of similar significance, and on the availability of such species or stocks for taking for certain subsistence uses (referred to in shorthand as “mitigation”); and requirements pertaining to the mitigation, monitoring and reporting of such takings are set forth.
On March 16, 2018, NMFS received a request from the L-DEO for an IHA to take marine mammals incidental to conducting a marine geophysical survey in the North Pacific Ocean. L-DEO submitted a revised application on June 11, 2018. On June 13, 2018, we deemed L-DEO's application for authorization to be adequate and complete. L-DEO's request is for take of small numbers of 39 species of marine mammals by Level A and Level B harassment. Underwater sound associated with airgun use may result in the behavioral harassment or auditory injury of marine mammals in the ensonified areas. Mortality is not an anticipated outcome of airgun surveys such as this, and, therefore, an IHA is appropriate.
NMFS has issued an IHA to L-DEO authorizing the take of 39 species by Level A and Level B harassment. The IHA is effective from September 1, 2018 through August 31, 2019.
The planned activity consists of two high-energy seismic surveys conducted at different locations in the North Pacific Ocean. Researchers from L-DEO and University of Hawaii, with funding from the U.S. National Science Foundation (NSF), in collaboration with researchers from United States Geological Survey (USGS), Oxford University, and GEOMAR Helmholtz Centre for Ocean Research Kiel (GEOMAR), plan to conduct the surveys from the Research Vessel (R/V)
The Hawaii survey would be expected to last for 38 days, including ~19 days of seismic operations, 11 days of equipment deployment/retrieval, ~5 days of operational contingency time (
Representative survey tracklines are shown in Figures 1 and 2 in the application. Water depths in the Hawaii survey area range from ~700 m to more than 5,000 m. The water depths in the Emperor Seamounts survey area range from 1,500-6,000 m. The Hawaii seismic survey will be conducted within the U.S. exclusive economic zone (EEZ); the Emperor Seamounts survey will take place in International Waters.
The procedures to be used for the planned surveys would be similar to those used during previous seismic surveys by L-DEO and would use conventional seismic methodology. The surveys would involve one source vessel, the
A detailed description of the planned project is provided in the
NMFS published a notice of proposed IHA in the
Regarding the Commission's recommendation that NMFS convene an internal working group to determine what data sources are considered best available for the various species and in the various areas, NMFS may consider future action to address these issues, but currently intends to address these questions through ongoing interactions with the U.S. Navy, academic institutions, and other research organizations.
In summary, use of the radius is not inconsistent with how isopleths have been calculated for other sources, including seismic activities. Use of the radius will also account for animals at depth that are at the longest radial distance. Note that the use of radial distance was used only to establish modified far-field source levels.
Results show that the adjustment factors slightly decrease for scenarios C and D and the corresponding PTS SELcum Isopleths to thresholds are a little higher for those two scenarios (<20m) but are always smaller than the PTS SELcum Isopleths to thresholds derived from the Peak SPL that was used here.
L-DEO's application describes their approach to modeling Level A and Level B harassment zones. In summary, LDEO acquired field measurements for several array configurations at shallow, intermediate, and deep-water depths during acoustic verification studies conducted in the northern Gulf of Mexico in 2007 and 2008 (Tolstoy
In 2015, LDEO explored the question of whether the Gulf of Mexico calibration data described above adequately informs the model to predict exclusion isopleths in other areas by conducting a retrospective sound power analysis of one of the lines acquired during L-DEO's seismic survey offshore New Jersey in 2014 (Crone, 2015). NMFS presented a comparison of the predicted radii (
The following is a summary of two additional analyses of in-situ data that support LDEO's use of the modeled Level A and Level B harassment zones in this particular case. In 2010, LDEO assessed the accuracy of their modeling approach by comparing the sound levels of the field measurements acquired in the Gulf of Mexico study to their model predictions (Diebold
NMFS continues to work with LDEO to address the issue of incorporating site-specific information for future authorizations for seismic surveys. However, LDEO's current modeling approach (supported by the three data points discussed previously) represents the best available information for NMFS to reach determinations for this IHA. As described earlier, the comparisons of LDEO's model results and the field data collected at multiple locations (
LDEO has conveyed to NMFS that additional modeling efforts to refine the process and conduct comparative analysis may be possible with the availability of research funds and other resources. Obtaining research funds is typically accomplished through a competitive process, including those submitted to U.S. Federal agencies. The use of models for calculating Level A and Level B harassment zones and for developing take estimates is not a requirement of the MMPA incidental take authorization process. Further, NMFS does not provide specific guidance on model parameters nor prescribe a specific model for applicants as part of the MMPA incidental take authorization process at this time, although we do review methods to ensure adequate for prediction of take. There is a level of variability not only with parameters in the models, but also the uncertainty associated with data used in models, and therefore, the quality of the model results submitted by applicants. NMFS considers this variability when evaluating applications and the take estimates and mitigation measures that the model informs. NMFS takes into consideration the model used, and its results, in determining the potential impacts to marine mammals; however, it is just one component of the analysis during the MMPA authorization process as NMFS also takes into consideration other factors associated with the activity (
L-DEO has met with the Commission and NMFS on several occasions to explain the model and why it is, although conservative, the most appropriate approach to use for
Note that powerdowns are only allowed/required in lieu of shutdown when certain species of dolphins, specifically identified in the
A modeling exercise was conducted as a follow-up to the McCauley
In the absence of further validation of the McCauley
Section 4 of the IHA application summarizes available information regarding status and trends, distribution and habitat preferences, and behavior and life history of the potentially affected species. More general information about these species (
Twenty-eight cetacean species, including 21 odontocetes (dolphins and small- and large-toothed whales) and seven mysticetes (baleen whales), and one pinniped species, could occur in the planned Hawaii survey area (Table 4). In the Emperor Seamounts survey area, 27 marine mammal species could occur, including 15 odontocetes (dolphins and small- and large-toothed whales), eight mysticetes (baleen whales), and four pinniped species. Some species occur in both locations. In total, 39 species are expected to occur in the vicinity of the specified activity.
Marine mammal abundance estimates presented in this document represent the total number of individuals estimated within a particular study or survey area. All values presented in Table 1 are the most recent available at the time of publication.
All species that could potentially occur in the planned survey area are included in Table 1. With the exception of Steller sea lions, these species or stocks temporally and spatially co-occur with the activity to the degree that take is reasonably likely to occur. However, the temporal and/or spatial occurrence of Steller sea lions is such that take is not expected to occur, and they are not discussed further beyond the explanation provided here. The Steller sea lion occurs along the North Pacific Rim from northern Japan to California (Loughlin
A detailed description of the of the species likely to be affected by the planned project, including brief introductions to the species and relevant stocks as well as available information regarding population trends and threats, and information regarding local occurrence, were provided in the
The effects of underwater noise from marine geophysical survey activities have the potential to result in behavioral harassment and, in a limited number of instances, auditory injury (PTS) of marine mammals in the vicinity of the action area. The
This section provides an estimate of the number of incidental takes authorized through this IHA, which will inform both NMFS' consideration of whether the number of takes is “small” and the negligible impact determination. As described in detail below, modifications have been made to several take estimates based on recommendations from the public regarding density or occurrence of certain marine mammal species or stocks.
Harassment is the only type of take expected to result from these activities. Except with respect to certain activities not pertinent here, section 3(18) of the MMPA defines “harassment” as: any act of pursuit, torment, or annoyance which (i) has the potential to injure a marine mammal or marine mammal stock in the wild (Level A harassment); or (ii) has the potential to disturb a marine mammal or marine mammal stock in the wild by causing disruption of behavioral patterns, including, but not limited to, migration, breathing, nursing, breeding, feeding, or sheltering (Level B harassment).
Authorized takes would primarily be by Level B harassment, as use of seismic airguns has the potential to result in disruption of behavioral patterns for individual marine mammals. There is also some potential for auditory injury (Level A harassment) for mysticetes and high frequency cetaceans (
Auditory injury is unlikely to occur for mid-frequency species given very small modeled zones of injury for those species (13.6 m). Moreover, the source level of the array is a theoretical definition assuming a point source and measurement in the far-field of the source (MacGillivray, 2006). As described by Caldwell and Dragoset (2000), an array is not a point source, but one that spans a small area. In the far-field, individual elements in arrays will effectively work as one source because individual pressure peaks will have coalesced into one relatively broad pulse. The array can then be considered a “point source.” For distances within the near-field,
As described previously, no mortality is anticipated or authorized for this activity. Below we describe how the take is estimated.
Described in the most basic way, we estimate take by considering: (1) Acoustic thresholds above which NMFS believes the best available science indicates marine mammals will be behaviorally harassed or incur some degree of permanent hearing impairment; (2) the area or volume of water that will be ensonified above these levels in a day; (3) the density or occurrence of marine mammals within these ensonified areas; and (4) and the number of days of activities. Below, we describe these components in more detail and present the exposure estimate and associated numbers of authorized takes.
Using the best available science, NMFS has developed acoustic thresholds that identify the received level of underwater sound above which exposed marine mammals would be reasonably expected to be behaviorally harassed (equated to Level B harassment) or to incur PTS of some degree (equated to Level A harassment).
These thresholds were developed by compiling and synthesizing the best available science and soliciting input multiple times from both the public and peer reviewers to inform the final product, and are provided in Table 2 below. The references, analysis, and methodology used in the development of the thresholds are described in NMFS 2016 Technical Guidance. As described above, L-DEO's activity includes the use of intermittent and impulsive seismic sources.
Here, we describe operational and environmental parameters of the activity that will feed into estimating the area ensonified above the relevant acoustic thresholds.
The surveys will acquire data with the 36-airgun array with a total discharge of 6,600 in
For deep and intermediate-water cases, the field measurements cannot be used readily to derive Level A and Level
In deep and intermediate-water depths, comparisons at short ranges between sound levels for direct arrivals recorded by the calibration hydrophone and model results for the same array tow depth are in good agreement (Fig. 12 and 14 in Appendix H of NSF-USGS, 2011). Consequently, isopleths falling within this domain can be predicted reliably by the L-DEO model, although they may be imperfectly sampled by measurements recorded at a single depth. At greater distances, the calibration data show that seafloor-reflected and sub-seafloor-refracted arrivals dominate, whereas the direct arrivals become weak and/or incoherent. Aside from local topography effects, the region around the critical distance is where the observed levels rise closest to the model curve. However, the observed sound levels are found to fall almost entirely below the model curve. Thus, analysis of the GoM calibration measurements demonstrates that although simple, the L-DEO model is a robust tool for conservatively estimating isopleths.
For deep water (>1,000 m), L-DEO used the deep-water radii obtained from model results down to a maximum water depth of 2000 m. The radii for intermediate water depths (100-1,000 m) were derived from the deep-water ones by applying a correction factor (multiplication) of 1.5, such that observed levels at very near offsets fall below the corrected mitigation curve (See Fig. 16 in Appendix H of NSF-USGS, 2011).
Measurements have not been reported for the single 40-in
L-DEO's modeling methodology is described in greater detail in the IHA application (LGL 2018). The estimated distances to the Level B harassment isopleth for the
Predicted distances to Level A harassment isopleths, which vary based on marine mammal hearing groups, were calculated based on modeling performed by L-DEO using the NUCLEUS software program and the NMFS User Spreadsheet, described below. The updated acoustic thresholds for impulsive sounds (
The values for SEL
In order to more realistically incorporate the Technical Guidance's weighting functions over the seismic array's full acoustic band, unweighted spectrum data for the
Inputs to the User Spreadsheets in the form of estimated SLs are shown in Table 5. User Spreadsheets used by L-DEO to estimate distances to Level A harassment isopleths for the 36-airgun array and single 40 in
Note that because of some of the assumptions included in the methods used, isopleths produced may be overestimates to some degree, which will ultimately result in some degree of overestimate of Level A harassment. However, these tools offer the best way to predict appropriate isopleths when more sophisticated modeling methods are not available, and NMFS continues to develop ways to quantitatively refine these tools and will qualitatively address the output where appropriate. For mobile sources, such as the planned seismic survey, the User Spreadsheet predicts the closest distance at which a stationary animal would not incur PTS if the sound source traveled by the animal in a straight line at a constant speed.
In this section we provide the information about the presence, density, or group dynamics of marine mammals that will inform the take calculations. The best available scientific information was considered in conducting marine mammal exposure estimates (the basis for estimating take).
In the planned survey area in the Hawaiian EEZ, densities from Bradford
For Hawaiian monk seals, NMFS followed the methods used by the U.S. Navy (Navy 2017a) to determine densities. The U.S. Navy calculated density of Hawaiian monk seal for three areas: The Main Hawaiian Islands in waters less than 200 meters, the Northwest Hawaiian Islands in waters less than 200 meters, and waters 200 meters deep to the Hawaiian EEZ boundary.
The 200 meter isobath was selected as a boundary because of information related to Hawaiian monk seal foraging behavior that came out of the final rule for designated critical habitat. Ninety-eight percent of recorded dives were within the 200-meter isobath in the Main Hawaiian Islands this depth boundary was considered sufficient for foraging habitat for adults and juveniles. The area around the Main Hawaiian Islands to the 200-meter isobath was estimated to be 6,630 km
The U.S. Navy used the following calculation to estimate density:
By applying the U.S. Navy's methodology using updated population estimates for the 2017 stock assessment report for the U.S. Pacific (Carretta
Based on where the action will occur, it NMFS utilized the density estimate for the Hawaiian EEZ.
There are very few published data on the densities of cetaceans or pinnipeds in the Emperor Seamounts area, so NMFS relied on a range of sources to establish marine mammal densities. As part of the Navy's Final Supplemental Environmental Impact Statement/Supplemental Overseas Environmental Impact Statement for SURTASS LFA Sonar Routine Training, Testing, and Military Operations, the Navy modelled densities for a designated mission area northeast of Japan during the summer season. These values were used for the North Pacific right whale, sei whale, fin whale, sperm whale, Cuvier's beaked whale, Stejneger's beaked whale, and Baird's beaked whale.
For northern right whale dolphin, Dall's porpoise, and northern fur seal, L-DEO used densities from Buckland
The short-beaked common dolphin is expected to be rare in the Emperor Seamounts survey area; thus, there are no density estimates available. L-DEO used the mean group size (rounded up) for the California Current from Barlow (2016). The density of Bryde's whale in the planned survey area was assumed to be zero, based on information from Hakamada
The densities for the remaining species were obtained from calculations using data from the papers presented to the IWC. For blue and humpback whales, L-DEO used a weighted mean density from Matsuoka
Finally, no northern elephant seals have been reported during any of the above surveys although Buckland
Here we describe how the information provided above is brought together to produce a quantitative take estimate. In order to estimate the number of marine mammals predicted to be exposed to sound levels that would result in Level A harassment or Level B harassment, radial distances from the airgun array to predicted isopleths corresponding to the Level A harassment and Level B harassment thresholds are calculated, as described above. Those radial distances are then used to calculate the area(s) around the airgun array predicted to be ensonified to sound levels that exceed the Level A harassment and Level B harassment thresholds. The area estimated to be ensonified in a single
NMFS calculated ensonified area along the tracklines to arrive at a total of 3,940-km
L-DEO is required to shutdown whenever a melon-headed whale is detected while passing through the Kohala resident stock's range. L-DEO
During the survey along Trackline 1 a short time will be spent traversing the northern boundary of the Hawaiian Island stock while along Trackline 2 the survey will run through the northwest boundary of the Oahu stock. The vast majority of planned survey tracklines occur in waters that are greater than 1,000 m which marks the boundary between the Hawaiian pelagic and Hawaiian insular stocks. According to a GIS analysis, an estimated 0.47 percent of all Hawaii tracklines will take place in waters less than 1,000 m deep northwest of Oahu along Trackline 2 and 1.00 percent will occur in depths less than 1,000 m north of Hawaii along Trackline 1. Therefore, NMFS will assume that the remaining 98.5% percent (588) of total takes will be accrued by the pelagic stock, 0.5 percent (3) will accrue to the Oahu stock and 1 percent (6) will accrue to the Hawaiian Island stock. Insular stocks have an average group size of group size of 8.5 rounded up to 9, so 9 takes will accrue to the Oahu stock and 9 takes to the Hawaiian Island stock (Baird
For Hawaiian monk seals, NMFS used an updated abundance estimate (Baker
The only stocks that occur in both the Emperor Seamounts and the Hawaiian Islands are the Central North Pacific (CNP) humpback whale, Western North Pacific (WNP) humpback whale, and Central North Pacific (CNP) blue whale stocks. NMFS combined take estimates from both surveys and calculated the percentage of each stock taken. The results were 0.18 percent for the CNP humpback stock, 0.36 percent for the WNP humpback stock, and 7.5 percent for the CNP blue whale stock.
It should be noted that authorized take numbers shown in Tables 7 and 8 are expected to be conservative for several reasons. First, in the calculations of estimated take, 25 percent has been added in the form of operational survey days to account for the possibility of additional seismic operations associated with airgun testing and repeat coverage of any areas where initial data quality is sub-standard, and in recognition of the uncertainties in the density estimates used to estimate take as described above. Additionally, marine mammals would be expected to move away from a loud sound source that represents an aversive stimulus, such as an airgun array, potentially reducing the number of Level A takes. However, the extent to which marine mammals would move away from the sound source is difficult to quantify and is, therefore, not accounted for in the take estimates.
In order to issue an IHA under Section 101(a)(5)(D) of the MMPA, NMFS must set forth the permissible methods of taking pursuant to such activity, “and other means of effecting the least practicable impact on such species or stock and its habitat, paying particular attention to rookeries, mating grounds, and areas of similar significance, and on the availability of such species or stock for taking” for certain subsistence uses (latter not applicable for this action). NMFS regulations require applicants for incidental take authorizations to include information about the availability and feasibility (economic and technological) of equipment, methods, and manner of conducting such activity or other means of effecting the least practicable adverse impact upon the affected species or stocks and their habitat (50 CFR 216.104(a)(11)).
In evaluating how mitigation may or may not be appropriate to ensure the least practicable adverse impact on species or stocks and their habitat, as well as subsistence uses where applicable, we carefully consider two primary factors:
(1) The manner in which, and the degree to which, the successful implementation of the measure(s) is expected to reduce impacts to marine mammals, marine mammal species or stocks, and their habitat. This considers the nature of the potential adverse impact being mitigated (likelihood, scope, range). It further considers the likelihood that the measure will be effective if implemented (probability of accomplishing the mitigating result if implemented as planned) the likelihood of effective implementation (probability implemented as planned), and
(2) the practicability of the measures for applicant implementation, which may consider such things as cost, impact on operations.
L-DEO has reviewed mitigation measures employed during seismic research surveys authorized by NMFS under previous incidental harassment authorizations, as well as recommended best practices in Richardson
To reduce the potential for disturbance from acoustic stimuli associated with the activities, L-DEO will implement mitigation measures for marine mammals. Mitigation measures that will be adopted during the planned surveys include (1) Vessel-based visual mitigation monitoring; (2) Vessel-based passive acoustic monitoring; (3) Establishment of an exclusion zone; (4) Power down procedures; (5) Shutdown procedures; (6) Ramp-up procedures; and (7) Vessel strike avoidance measures. Note that additional measures have been included in the final IHA that were not contained in the proposed IHA. These measures are described in the following sections.
Visual monitoring requires the use of trained observers (herein referred to as visual PSOs) to scan the ocean surface visually for the presence of marine mammals. The area to be scanned visually includes primarily the exclusion zone, but also the buffer zone. The buffer zone means an area beyond the exclusion zone to be monitored for the presence of marine mammals that may enter the exclusion zone. During pre-clearance monitoring (
L-DEO must use at least five dedicated, trained, NMFS-approved Protected Species Observers (PSOs). The PSOs must have no tasks other than to conduct observational effort, record observational data, and communicate with and instruct relevant vessel crew with regard to the presence of marine mammals and mitigation requirements. PSO resumes shall be provided to NMFS for approval.
At least one of the visual and two of the acoustic PSOs aboard the vessel must have a minimum of 90 days at-sea experience working in those roles, respectively, during a deep penetration (
During survey operations (
During use of the airgun (
For the final IHA, NMFS had added the requirement L-DEO must make a good faith effort to schedule their surveys to maximize the amount of seismic activity that takes place during daylight hours within the defined ranges of the Kohala resident stock of melon-headed whale and the Main Hawaiian Islands insular stock of fales killer whales. This will greatly assist PSOs in their efforts to effectively monitor these species. Furthermore, L-DEO must implement shutdown procedures if a melon-headed whale or group of melon-headed whales is observed in the Kohala resident stock's range.
Acoustic monitoring means the use of trained personnel (sometimes referred to as passive acoustic monitoring (PAM) operators, herein referred to as acoustic PSOs) to operate PAM equipment to acoustically detect the presence of marine mammals. Acoustic monitoring involves acoustically detecting marine mammals regardless of distance from the source, as localization of animals may not always be possible. Acoustic monitoring is intended to further support visual monitoring (during daylight hours) in maintaining an exclusion zone around the sound source that is clear of marine mammals. In cases where visual monitoring is not effective (
PAM would take place in addition to the visual monitoring program. Visual monitoring typically is not effective during periods of poor visibility or at night, and even with good visibility, if PSOs are unable to detect marine mammals when they are below the surface or beyond visual range. Acoustical monitoring can be used in addition to visual observations to improve detection, identification, and localization of cetaceans. The acoustic monitoring would serve to alert visual PSOs when vocalizing cetaceans are detected. It is only useful when marine mammals call, but it can be effective either by day or by night, and does not depend on good visibility. It would be monitored in real time so that the visual observers can be advised when cetaceans are detected.
The
Survey activity may continue for 30 minutes when the PAM system malfunctions or is damaged, while the PAM operator diagnoses the issue. If the diagnosis indicates that the PAM system must be repaired to solve the problem, operations may continue for an additional five hours without acoustic monitoring during daylight hours. In the proposed IHA, NMFS stated that only two hours of operations would be allowed without acoustic monitoring. However, L-DEO reported that approximately five hours are required to redeploy the spare PAM system if the primary PAM system fails. Note that operations may continue only under the following conditions:
• Sea state is less than or equal to BSS 4;
• No marine mammals (excluding delphinids) detected solely by PAM in the applicable exclusion zone in the previous two hours;
• NMFS is notified via email as soon as practicable with the time and location in which operations began occurring without an active PAM system; and
• Operations with an active acoustic source, but without an operating PAM system, do not exceed a cumulative total of five hours in any 24-hour period.
An exclusion zone (EZ) is a defined area within which occurrence of a marine mammal triggers mitigation action intended to reduce the potential for certain outcomes,
The 500 m EZ is intended to be precautionary in the sense that it would be expected to contain sound exceeding the injury criteria for all cetacean hearing groups, (based on the dual criteria of SELcum and peak SPL), while also providing a consistent, reasonably observable zone within which PSOs would typically be able to conduct effective observational effort. Additionally, a 500 m EZ is expected to minimize the likelihood that marine mammals will be exposed to levels likely to result in more severe behavioral responses. Although significantly greater distances may be observed from an elevated platform under good conditions, we believe that 500 m is likely regularly attainable for PSOs using the naked eye during typical conditions.
Ramp-up (sometimes referred to as “soft start”) means the gradual and systematic increase of emitted sound levels from an airgun array. Ramp-up begins by first activating a single airgun of the smallest volume, followed by doubling the number of active elements in stages until the full complement of an array's airguns are active. Each stage should be approximately the same duration, and the total duration should not be less than approximately 20 minutes. The intent of pre-clearance observation (30 minutes) is to ensure no protected species are observed within the buffer zone prior to the beginning of ramp-up. During pre-clearance is the only time observations of protected species in the buffer zone would prevent operations (
• The operator must notify a designated PSO of the planned start of ramp-up as agreed upon with the lead PSO; the notification time should not be less than 60 minutes prior to the planned ramp-up in order to allow the PSOs time to monitor the exclusion and buffer zones for 30 minutes prior to the initiation of ramp-up (pre-clearance).
• Ramp-ups shall be scheduled so as to minimize the time spent with the source activated prior to reaching the designated run-in.
• One of the PSOs conducting pre-clearance observations must be notified again immediately prior to initiating ramp-up procedures and the operator must receive confirmation from the PSO to proceed.
• Ramp-up may not be initiated if any marine mammal is within the applicable exclusion or buffer zone. If a marine mammal is observed within the applicable exclusion zone or the buffer zone during the 30 minute pre-clearance period, ramp-up may not begin until the animal(s) has been observed exiting the zones or until an additional time period has elapsed with no further sightings (15 minutes for small odontocetes and 30 minutes for all other species).
• Ramp-up shall begin by activating a single airgun of the smallest volume in the array and shall continue in stages by doubling the number of active elements at the commencement of each stage, with each stage of approximately the same duration. Duration shall not be less than 20 minutes. The operator must
• PSOs must monitor the exclusion and buffer zones during ramp-up, and ramp-up must cease and the source must be shut down upon observation of a marine mammal within the applicable exclusion zone. Once ramp-up has begun, observations of marine mammals within the buffer zone do not require shutdown or powerdown, but such observation shall be communicated to the operator to prepare for the potential shutdown or powerdown.
• Ramp-up may occur at times of poor visibility, including nighttime, if appropriate acoustic monitoring has occurred with no detections in the 30 minutes prior to beginning ramp-up. Acoustic source activation may only occur at times of poor visibility where operational planning cannot reasonably avoid such circumstances.
• If the acoustic source is shut down for brief periods (
• Testing of the acoustic source involving all elements requires ramp-up. Testing limited to individual source elements or strings does not require ramp-up but does require pre-clearance of 30 min.
The shutdown of an airgun array requires the immediate de-activation of all individual airgun elements of the array while a powerdown requires immediate de-activation of all individual airgun elements of the array except the single 40-in
• A marine mammal appears within or enters the applicable exclusion zone; and
• A marine mammal (other than delphinids, see below) is detected acoustically and localized within the applicable exclusion zone.
The shutdown requirements described below have been added to the final IHA as they were not included in the proposed IHA. Under the following conditions L-DEO must implement shutdown:
• A marine mammal species, for which authorization was granted but the takes have been met, approaches the Level A or B harassment zones;
• A large whale with a calf or an aggregation of large whales is observed regardless of the distance from the
• A melon-headed whale or group of melon-headed whales is observed in the range of the Kohala resident stock. This stock is found off the the Kohala Peninsula and west coast of Hawaii Island and at a depth of less than 2,500 m (Carretta
• A spinner or bottlenose dolphin or group of dolphins is observed approaching or is within the Level B harassment zone in the habitat of the specific MHI insular stock if the authorized takes have been met for any of these stocks.
When shutdown is called for by a PSO, the acoustic source will be immediately deactivated and any dispute resolved only following deactivation. Additionally, shutdown will occur whenever PAM alone (without visual sighting), confirms presence of marine mammal(s) in the EZ. If the acoustic PSO cannot confirm presence within the EZ, visual PSOs will be notified but shutdown is not required.
Following a shutdown, airgun activity would not resume until the marine mammal has cleared the 500 m EZ. The animal would be considered to have cleared the 500 m EZ if it is visually observed to have departed the 500 m EZ, or it has not been seen within the 500 m EZ for 15 min in the case of small odontocetes and pinnipeds, or 30 min in the case of mysticetes and large odontocetes, including sperm, pygmy sperm, dwarf sperm, and beaked whales.
The shutdown requirement can be waived for small dolphins in which case the acoustic source shall be powered down to the single 40-in
Powerdown conditions shall be maintained until delphinids for which shutdown is waived are no longer observed within the 500 m exclusion zone, following which full-power operations may be resumed without ramp-up. Visual PSOs may elect to waive the powerdown requirement if delphinids for which shutdown is waived appear to be voluntarily approaching the vessel for the purpose of interacting with the vessel or towed gear, and may use best professional judgment in making this decision.
We include this small delphinoid exception because power-down/shutdown requirements for small delphinoids under all circumstances represent practicability concerns without likely commensurate benefits for the animals in question. Small delphinoids are generally the most commonly observed marine mammals in the specific geographic region and would typically be the only marine mammals likely to intentionally approach the vessel. As described above, auditory injury is extremely
A large body of anecdotal evidence indicates that small delphinoids commonly approach vessels and/or towed arrays during active sound production for purposes of bow riding, with no apparent effect observed in those delphinoids (
Visual PSOs shall use best professional judgment in making the decision to call for a shutdown if there is uncertainty regarding identification (
Upon implementation of shutdown, the source may be reactivated after the marine mammal(s) has been observed exiting the applicable exclusion zone (
In the event of a live stranding (or near-shore atypical milling) event, L-DEO must adhere to recently established protocols, which were not contained in the proposed IHA. If the stranding event occurs within 50 km of the survey operations, where the NMFS stranding network is engaged in herding or other interventions to return animals to the water, the Director of OPR, NMFS (or designee) will advise the IHA-holder of the need to implement shutdown procedures for all active acoustic sources operating within 50 km of the stranding. Shutdown procedures for live stranding or milling marine mammals include the following:
• If at any time, the marine mammal(s) die or are euthanized, or if herding/intervention efforts are stopped, the Director of OPR, NMFS (or designee) will advise the IHA-holder that the shutdown around the animals' location is no longer needed.
• Otherwise, shutdown procedures will remain in effect until the Director of OPR, NMFS (or designee) determines and advises the IHA-holder that all live animals involved have left the area (either of their own volition or following an intervention).
• If further observations of the marine mammals indicate the potential for re-stranding, additional coordination with the IHA-holder will be required to determine what measures are necessary to minimize that likelihood (
Shutdown procedures are not related to the investigation of the cause of the stranding and their implementation is not intended to imply that the specified activity is the cause of the stranding. Rather, shutdown procedures are intended to protect marine mammals exhibiting indicators of distress by minimizing their exposure to possible additional stressors, regardless of the factors that contributed to the stranding.
These measures apply to all vessels associated with the planned survey activity; however, we note that these requirements do not apply in any case where compliance would create an imminent and serious threat to a person or vessel or to the extent that a vessel is restricted in its ability to maneuver and, because of the restriction, cannot comply. These measures include the following:
1. Vessel operators and crews must maintain a vigilant watch for all marine mammals and slow down, stop their vessel, or alter course, as appropriate and regardless of vessel size, to avoid striking any marine mammal. A single marine mammal at the surface may indicate the presence of submerged animals in the vicinity of the vessel; therefore, precautionary measures should be exercised when an animal is observed. A visual observer aboard the vessel must monitor a vessel strike avoidance zone around the vessel (specific distances detailed below), to ensure the potential for strike is minimized. Visual observers monitoring the vessel strike avoidance zone can be either third-party observers or crew members, but crew members responsible for these duties must be provided sufficient training to distinguish marine mammals from other phenomena and broadly to identify a marine mammal to broad taxonomic group (
2. Vessel speeds must be reduced to 10 kn or less when mother/calf pairs, pods, or large assemblages of any marine mammal are observed near a vessel.
3. All vessels must maintain a minimum separation distance of 100 m from large whales (
4. All vessels must attempt to maintain a minimum separation distance of 50 m from all other marine mammals, with an exception made for those animals that approach the vessel.
5. When marine mammals are sighted while a vessel is underway, the vessel should take action as necessary to avoid violating the relevant separation distance (
We have carefully evaluated the suite of mitigation measures described here and considered a range of other measures in the context of ensuring that we prescribe the means of effecting the least practicable adverse impact on the affected marine mammal species and stocks and their habitat. Based on our evaluation of the planned measures, NMFS has determined that the mitigation measures provide the means effecting the least practicable impact on the affected species or stocks and their habitat, paying particular attention to rookeries, mating grounds, and areas of similar significance.
In order to issue an IHA for an activity, section 101(a)(5)(D) of the MMPA states that NMFS must set forth, requirements pertaining to the monitoring and reporting of such taking. The MMPA implementing regulations at 50 CFR 216.104(a)(13) indicate that requests for authorizations must include the suggested means of accomplishing the necessary monitoring and reporting that will result in increased knowledge of the species and of the level of taking or impacts on populations of marine mammals that are expected to be present in the action area. Effective reporting is critical both to compliance as well as ensuring that the most value is obtained from the required monitoring.
Monitoring and reporting requirements prescribed by NMFS should contribute to improved understanding of one or more of the following:
• Occurrence of marine mammal species or stocks in the area in which take is anticipated (
• Nature, scope, or context of likely marine mammal exposure to potential stressors/impacts (individual or cumulative, acute or chronic), through better understanding of: (1) Action or environment (
• Individual marine mammal responses (behavioral or physiological) to acoustic stressors (acute, chronic, or cumulative), other stressors, or cumulative impacts from multiple stressors.
• How anticipated responses to stressors impact either: (1) Long-term fitness and survival of individual marine mammals; or (2) populations, species, or stocks.
• Effects on marine mammal habitat (
• Mitigation and monitoring effectiveness.
As described above, PSO observations would take place during daytime airgun operations and nighttime start ups (if applicable) of the airguns. During seismic operations, at least five visual PSOs would be based aboard the
• The operator shall provide PSOs with bigeye binoculars (
• The operator will work with the selected third-party observer provider to ensure PSOs have all equipment (including backup equipment) needed to adequately perform necessary tasks, including accurate determination of distance and bearing to observed marine mammals. (c) PSOs must have the following requirements and qualifications:
• PSOs shall be independent, dedicated, trained visual and acoustic PSOs and must be employed by a third-party observer provider.
• PSOs shall have no tasks other than to conduct observational effort (visual or acoustic), collect data, and communicate with and instruct relevant vessel crew with regard to the presence of protected species and mitigation requirements (including brief alerts regarding maritime hazards),
• PSOs shall have successfully completed an approved PSO training course appropriate for their designated task (visual or acoustic). Acoustic PSOs are required to complete specialized training for operating PAM systems and are encouraged to have familiarity with the vessel with which they will be working.
• PSOs can act as acoustic or visual observers (but not at the same time) as long as they demonstrate that their training and experience are sufficient to perform the task at hand.
• NMFS must review and approve PSO resumes accompanied by a relevant training course information packet that includes the name and qualifications (
• NMFS shall have one week to approve PSOs from the time that the necessary information is submitted, after which PSOs meeting the minimum requirements shall automatically be considered approved.
• PSOs must successfully complete relevant training, including completion of all required coursework and passing (80 percent or greater) a written and/or oral examination developed for the training program.
• PSOs must have successfully attained a bachelor's degree from an accredited college or university with a major in one of the natural sciences, a minimum of 30 semester hours or equivalent in the biological sciences, and at least one undergraduate course in math or statistics.
• The educational requirements may be waived if the PSO has acquired the relevant skills through alternate experience. Requests for such a waiver shall be submitted to NMFS and must include written justification. Requests shall be granted or denied (with justification) by NMFS within one week of receipt of submitted information. Alternate experience that may be considered includes, but is not limited to (1) secondary education and/or experience comparable to PSO duties; (2) previous work experience conducting academic, commercial, or government-sponsored protected species surveys; or (3) previous work experience as a PSO; the PSO should demonstrate good standing and consistently good performance of PSO duties.
For data collection purposes, PSOs shall use standardized data collection forms, whether hard copy or electronic. PSOs shall record detailed information about any implementation of mitigation requirements, including the distance of animals to the acoustic source and description of specific actions that ensued, the behavior of the animal(s), any observed changes in behavior before and after implementation of mitigation, and if shutdown was implemented, the length of time before any subsequent ramp-up of the acoustic source. If required mitigation was not implemented, PSOs should record a description of the circumstances. At a minimum, the following information must be recorded:
• Vessel names (source vessel and other vessels associated with survey) and call signs;
• PSO names and affiliations;
• Dates of departures and returns to port with port name;
• Dates and times (Greenwich Mean Time) of survey effort and times corresponding with PSO effort;
• Vessel location (latitude/longitude) when survey effort began and ended and vessel location at beginning and end of visual PSO duty shifts;
• Vessel heading and speed at beginning and end of visual PSO duty shifts and upon any line change;
• Environmental conditions while on visual survey (at beginning and end of PSO shift and whenever conditions
• Factors that may have contributed to impaired observations during each PSO shift change or as needed as environmental conditions changed (
• Survey activity information, such as acoustic source power output while in operation, number and volume of airguns operating in the array, tow depth of the array, and any other notes of significance (
The following information should be recorded upon visual observation of any protected species:
• Watch status (sighting made by PSO on/off effort, opportunistic, crew, alternate vessel/platform);
• PSO who sighted the animal;
• Time of sighting;
• Vessel location at time of sighting;
• Water depth;
• Direction of vessel's travel (compass direction);
• Direction of animal's travel relative to the vessel;
• Pace of the animal;
• Estimated distance to the animal and its heading relative to vessel at initial sighting;
• Identification of the animal (
• Estimated number of animals (high/low/best);
• Estimated number of animals by cohort (adults, yearlings, juveniles, calves, group composition, etc.);
• Description (as many distinguishing features as possible of each individual seen, including length, shape, color, pattern, scars or markings, shape and size of dorsal fin, shape of head, and blow characteristics);
• Detailed behavior observations (
• Animal's closest point of approach (CPA) and/or closest distance from any element of the acoustic source;
• Platform activity at time of sighting (
• Description of any actions implemented in response to the sighting (
If a marine mammal is detected while using the PAM system, the following information should be recorded:
• An acoustic encounter identification number, and whether the detection was linked with a visual sighting;
• Date and time when first and last heard;
• Types and nature of sounds heard (
• Any additional information recorded such as water depth of the hydrophone array, bearing of the animal to the vessel (if determinable), species or taxonomic group (if determinable), spectrogram screenshot, and any other notable information.
L-DEO will be required to shall submit a draft comprehensive report to NMFS on all activities and monitoring results within 90 days of the completion of the survey or expiration of the IHA, whichever comes sooner. The report must describe all activities conducted and sightings of protected species near the activities, must provide full documentation of methods, results, and interpretation pertaining to all monitoring, and must summarize the dates and locations of survey operations and all protected species sightings (dates, times, locations, activities, associated survey activities). The report must include estimates of the number and nature of exposures that occurred above the harassment threshold based on PSO observations, including an estimate of those on the trackline but not detected. The report must also include geo-referenced time-stamped vessel tracklines for all time periods during which airguns were operating. Tracklines should include points recording any change in airgun status (
NMFS has revised the standard protcols that apply when an injured or dead marine mammal is discovered and has included them here. These updated protocols were not described in the proposed IHA. In the event that personnel involved in survey activities covered by the authorization discover an injured or dead marine mammal, the IHA-holder shall report the incident to the Office of Protected Resources (OPR), NMFS and to the NMFS Pacific Islands Regional Stranding Coordinator as soon as feasible. The report must include the following information:
• Time, date, and location (latitude/longitude) of the first discovery (and updated location information if known and applicable);
• Species identification (if known) or description of the animal(s) involved;
• Condition of the animal(s) (including carcass condition if the animal is dead);
• Observed behaviors of the animal(s), if alive;
• If available, photographs or video footage of the animal(s); and
• General circumstances under which the animal was discovered.
• Status of all sound source use in the 48 hours preceding the estimated time of stranding and within 50 km of the discovery/notification of the stranding by NMFS; and
• If available, description of the behavior of any marine mammal(s) observed preceding (
Examples of circumstances that could trigger the additional information request include, but are not limited to, the following:
• Atypical nearshore milling events of live cetaceans;
• Mass strandings of cetaceans (two or more individuals, not including cow/calf pairs);
• Beaked whale strandings;
• Necropsies with findings of pathologies that are unusual for the species or area; or
• Stranded animals with findings consistent with blast trauma.
In the event that the investigation is still inconclusive, the investigation of the association of the survey activities is still warranted, and the investigation is still being pursued, NMFS may provide additional information requests, in writing, regarding the nature and location of survey operations prior to the time period above.
• Time, date, and location (latitude/longitude) of the incident;
• Species identification (if known) or description of the animal(s) involved;
• Vessel's speed during and leading up to the incident;
• Vessel's course/heading and what operations were being conducted (if applicable);
• Status of all sound sources in use;
• Description of avoidance measures/requirements that were in place at the time of the strike and what additional measures were taken, if any, to avoid strike;
• Environmental conditions (
• Estimated size and length of animal that was struck;
• Description of the behavior of the marine mammal immediately preceding and following the strike;
• If available, description of the presence and behavior of any other marine mammals immediately preceding the strike;
• Estimated fate of the animal (
• To the extent practicable, photographs or video footage of the animal(s).
NMFS has defined negligible impact as “an impact resulting from the specified activity that cannot be reasonably expected to, and is not reasonably likely to, adversely affect the species or stock through effects on annual rates of recruitment or survival” (50 CFR 216.103). A negligible impact finding is based on the lack of likely adverse effects on annual rates of recruitment or survival (
To avoid repetition, our analysis applies to all species listed in Table 7 and 8, given that NMFS expects the anticipated effects of the planned seismic survey to be similar in nature. Where there are meaningful differences between species or stocks, or groups of species, in anticipated individual responses to activities, impact of expected take on the population due to differences in population status, or impacts on habitat, NMFS has identified species-specific factors to inform the analysis.
NMFS does not anticipate that serious injury or mortality would occur as a result of L-DEO's planned surveys, even in the absence of planned mitigation. As discussed in the
NMFS has authorized a limited number of instances of Level A harassment of 6 species and Level B harassment of 39 marine mammal species. However, we believe that any PTS incurred in marine mammals as a result of the activity would be in the form of only a small degree of PTS, not total deafness, and would be unlikely to affect the fitness of any individuals, because of the constant movement of both the
Potential impacts to marine mammal habitat were discussed previously in this document (see
The activity is expected to impact a small percentage of all marine mammal stocks that would be affected by L-DEO's planned survey (less than 15 percent percent of all species, including those taken by both surveys). Additionally, the acoustic “footprint” of the planned surveys would be small relative to the ranges of the marine mammals that would potentially be affected. Sound levels would increase in the marine environment in a relatively small area surrounding the vessel compared to the range of the marine mammals within the planned survey area.
The required mitigation measures are expected to reduce the severity of takes by allowing for detection of marine
The ESA-listed marine mammal species under our jurisdiction that are likely to be taken by the planned surveys include the endangered sei, fin, blue, sperm, gray, North Pacific Right, Western North Pacific DPS humpback, and Main Hawaiian Islands Insular DPS false killer whale as well as the Hawaiian monk seal. We have authorized very small numbers of takes for these species relative to their population sizes. Therefore, we do not expect population-level impacts to any of these species. The other marine mammal species that may be taken by harassment during the survey are not listed as threatened or endangered under the ESA. With the exception of the northern fur seal, none of the non-listed marine mammals for which we have authorized take are considered “depleted” or “strategic” by NMFS under the MMPA.
The tracklines of the Hawaii survey either traverse or are proximal to BIAs for 11 species that NMFS has authorized for take. Ten of the BIAs pertain to small and resident cetacean populations while a breeding BIA has been delineated for humpback whales. However, this designation is only applicable to humpback whales in the December through March timeframe (Baird
NMFS has included a number of mitigation and monitoring measures to reduce potential impacts to small and resident populations in the Main Hawaiian Islands. Given the small population and large recorded group sizes of Kohala resident melon-headed whales, L-DEO must shut down when a melon-headed whale or group of melon-headed whales is observed in the range of the Kohala resident stock. Furthermore, L-DEO will plan to time their seismic operations along Trackline 1 so they will traverse the Kohala resident stock's range during daytime. L-DEO will similarly plan to conduct daylight crossings of designated critical habitat for the Main Hawaiian Island insular false killer whale. Spinner and bottlenose dolphin stocks also have small and resident populations. Therefore, when a group of dolphins is observed approaching or is within the Level B harassment zone in the habitat of the specific MHI insular stock L-DEO must shut down if the authorized takes have been met for any of these stocks. Additional protective measures include mandatory shutdown when a large whale with a calf or an aggregation of large whales is observed regardless of the distance from the Langseth;
NMFS concludes that exposures to marine mammal species and stocks due to L-DEO's planned survey would result in only short-term (temporary and short in duration) effects to individuals exposed. Animals may temporarily avoid the immediate area, but are not expected to permanently abandon the area. Major shifts in habitat use, distribution, or foraging success are not expected. NMFS does not anticipate that authorized take numbers will impact annual rates of recruitment or survival.
In summary and as described above, the following factors primarily support our determination that the impacts resulting from this activity are not expected to adversely affect the marine mammal species or stocks through effects on annual rates of recruitment or survival:
• No mortality is anticipated or authorized;
• The planned activity is temporary and of relatively short duration;
• The anticipated impacts of the activity on marine mammals would primarily be temporary behavioral changes due to avoidance of the area around the survey vessel;
• The number of instances of PTS that may occur are expected to be limited. Instances of PTS that are incurred in marine mammals would be of a low level, due to constant movement of the vessel and of the marine mammals in the area, and the nature of the survey design (not concentrated in areas of high marine mammal concentration);
• The availability of alternate areas of similar habitat value for marine mammals to temporarily vacate the survey area during the survey to avoid exposure to sounds from the activity;
• The potential adverse effects on fish or invertebrate species that serve as prey species for marine mammals from the survey will be temporary and spatially limited;
• The required mitigation measures, including visual and acoustic monitoring, power-downs, and shutdowns, are expected to minimize potential impacts to marine mammals. Specific mitigation measures added to this final IHA include shutting down when a large whale with a calf or an aggregation of large whales is observed; shutting down when a melon-headed whale or group of melon-headed whales is observed in the range of the Kohala resident stock; shutting down when a spinner or bottlenose dolphin or group of dolphins approach the Level B harassment zone in the habitat of the specific MHI insular stock if the authorized takes have been met for any of these stocks; and timing surveys to traverse ranges of the Kohala resident stock of melon-headed whale and the Main Hawaiian Islands insular stock of false killer whales during daylight hours.
Based on the analysis contained herein of the likely effects of the specified activity on marine mammals and their habitat, and taking into consideration the implementation of the required monitoring and mitigation measures, NMFS finds that the total marine mammal take from the planned activity will have a negligible impact on all affected marine mammal species or stocks.
As noted above, only small numbers of incidental take may be authorized under section 101(a)(5)(D) of the MMPA for specified activities other than military readiness activities. The MMPA does not define small numbers; so, in practice, where estimated numbers are available, NMFS compares the number of individuals taken to the most appropriate estimation of abundance of
The numbers of marine mammals for which we have authorized take across the two surveys would be considered small relative to the relevant populations (a maximum of 14.7 percent) for the species for which abundance estimates are available. Several small resident or insular populations that could experience Level B harassment during the Hawaii survey were discussed in the Estimated Take section. For the Kohala resident stock of melo-headed whales (pop. 447), NMFS assumed that up to 3 groups of 20 Kohala residents could be taken by Level B harassment, representing 13.4 percent of the Kohala stock, if they enter the zone undetected by PSOs. Additionally, the range of the Hawaiian Island stock overlaps the range of the Kohala resident stock. Therefore, any melon-headed whale takes within the Kohala resident stock's range could also be from either stock. Sesimic operations will occur in the ranges of the Hawaiian Island stock (pop. 128) and Oahu stock (pop. 743) of common bottlenose dolphins. Based on GIS analysis of the tracklines and the ranges of the stocks, NMFS determined that 7 percent of the Hawaii Island stock and 1.2 percent of the Oahu stock could be exposed to Level B harassment. Similar GIS analysis of the Hawaii Island (pop. 631) and Oahu/4-Island (pop. 355) stocks of spinner dolphins resulted in estimated Level B harassment of 3.8 percent of the Hawaii Islands stock population and 6.7 percent of the Oahu/4-Island stock population. Analysis of pantropical spotted dolphins determined that there would be 9 Oahu stock exposures and 82 Hawaii Island stock exposures. The populations of these stocks are unknown, so the percentage of stocks affected cannot be determined. However, the large ranges of these species (up to 20 km from Oahu and 65 km from Hawaii) make it likely that the survey would only impact limited numbers of these stocks.
Based on the analysis contained herein of the planned activity (including the required mitigation and monitoring measures) and the anticipated take of marine mammals, NMFS finds that small numbers of marine mammals will be taken relative to the population size of the affected species.
There are no relevant subsistence uses of the affected marine mammal stocks or species implicated by this action. Therefore, NMFS has determined that the total taking of affected species or stocks would not have an unmitigable adverse impact on the availability of such species or stocks for taking for subsistence purposes.
Section 7(a)(2) of the Endangered Species Act of 1973 (ESA: 16 U.S.C. 1531
The NMFS Permits and Conservation Division issued a Biological Opinion on August 24, 2018 to NMFS's Office of Protected Resources which concluded that the specified activities are not likely to jeopardize the continued existence of the North Pacific right whale, sei whale, fin whale, blue whale, sperm whale, Western North Pacific DPS humpback whale, gray whale, Hawaiian Islands Insular DPS false killer whale, and the Hawaiian monk seal or adversely modify critical habitat because none exists within the action area.
To comply with the National Environmental Policy Act of 1969 (NEPA; 42 U.S.C. 4321
Accordingly, NMFS has adopted the L-DEO Final Environmental Assessment (EA),
As a result of these determinations, we have issued an IHA to L-DEO for conducting seismic surveys in the Pacific Ocean near the main Hawaiian Islands and the Emperor Seamounts area from September 1, 2018 through August 31, 2019, provided the previously mentioned mitigation, monitoring, and reporting requirements are incorporated.
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice; public meeting.
The New England Fishery Management Council (Council) is scheduling a public meeting of its Groundfish Advisory Panel to consider actions affecting New England fisheries in the exclusive economic zone (EEZ). Recommendations from this group will be brought to the full Council for formal consideration and action, if appropriate.
This meeting will be held on Tuesday, September 18, 2018 at 8:30 a.m.
Thomas A. Nies, Executive Director, New England Fishery Management Council; telephone: (978) 465-0492.
The Advisory Panel will discuss Framework Adjustment 58: Specifications/Management Measures
Although non-emergency issues not contained in this agenda may come before this group for discussion, those issues may not be the subject of formal action during these meetings. Action will be restricted to those issues specifically listed in this notice and any issues arising after publication of this notice that require emergency action under section 305(c) of the Magnuson-Stevens Act, provided the public has been notified of the Council's intent to take final action to address the emergency. This meeting will be recorded. Consistent with 16 U.S.C. 1852, a copy of the recording is available upon request.
This meeting is physically accessible to people with disabilities. Requests for sign language interpretation or other auxiliary aids should be directed to Thomas A. Nies, Executive Director, at (978) 465-0492, at least 5 days prior to the meeting date.
16 U.S.C. 1801
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of public meeting.
The North Pacific Fishery Management Council (Council) Groundfish Plan Teams will meet September 18, 2018 through September 21, 2018.
The meetings will be held on Tuesday, September 18, 2018 through Friday, September 21, 2018, from 9 a.m. to 5 p.m.
The meetings will be held at the Alaska Fishery Science Center in the Traynor Room 2076 and NMML Room 2079, 7600 Sand Point Way NE, Building 4, Seattle, WA 98115.
Diana Stram or Jim Armstrong, Council staff; telephone: (907) 271-2809.
The Plan Teams will review the preliminary stock assessments for Groundfish and receive reports including but not limited to: 2018 Survey Estimates, CIE Reviews for GOA Pollock and BSAI Flatfish, and the Economic Stock Assessment and Fishery Evaluation (SAFE).
The Agenda is subject to change, and the latest version will be posted at
Public comment letters will be accepted and should be submitted either electronically to Jim Armstrong, Council staff:
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.
Committee for Purchase From People Who Are Blind or Severely Disabled.
Proposed addition to and deletions from the Procurement List.
The Committee is proposing to add products to the Procurement List that will be furnished by a nonprofit agency employing persons who are blind or have other severe disabilities, and delete products and services previously furnished by such agencies.
Comments must be received on or before: September 30, 2018.
Committee for Purchase From People Who Are Blind or Severely Disabled, 1401 S. Clark Street, Suite 715, Arlington, Virginia 22202-4149.
For further information or to submit comments contact: Michael R. Jurkowski, Telephone: (703) 603-2117, Fax: (703) 603-0655, or email
This notice is published pursuant to 41 U.S.C. 8503 (a)(2) and 41 CFR 51-2.3. Its purpose is to provide interested persons an opportunity to submit comments on the proposed actions.
If the Committee approves the proposed addition, the entities of the Federal Government identified in this notice will be required to procure the products listed below from a nonprofit agency employing persons who are blind or have other severe disabilities.
The following products are proposed for addition to the Procurement List for production by the nonprofit agency listed:
The following products and services are proposed for deletion from the Procurement List:
Committee for Purchase From People Who Are Blind or Severely Disabled.
Additions to and deletions from the Procurement List.
This action adds a product and a service to the Procurement List that will be furnished by nonprofit agencies employing persons who are blind or have other severe disabilities, and deletes products and services from the Procurement List previously furnished by such agencies.
Committee for Purchase From People Who Are Blind or Severely Disabled, 1401 S Clark Street, Suite 715, Arlington, Virginia 22202-4149.
Michael R. Jurkowski, Telephone: (703) 603-2117, Fax: (703) 603-0655, or email
On 5/25/2018(83 FR 102) and 6/8/2018 (83 FR 111), the Committee for Purchase From People Who Are Blind or Severely Disabled published notice of proposed additions to the Procurement List.
After consideration of the material presented to it concerning capability of qualified nonprofit agencies to provide the product and service and impact of the additions on the current or most recent contractors, the Committee has determined that the product and service listed below are suitable for procurement by the Federal Government under 41 U.S.C. 8501-8506 and 41 CFR 51-2.4.
I certify that the following action will not have a significant impact on a substantial number of small entities. The major factors considered for this certification were:
1. The action will not result in any additional reporting, recordkeeping or other compliance requirements for small entities other than the small organizations that will furnish the product and service to the Government.
2. The action will result in authorizing small entities to furnish the product and service to the Government.
3. There are no known regulatory alternatives which would accomplish the objectives of the Javits-Wagner-O'Day Act (41 U.S.C. 8501-8506) in connection with the product and service proposed for addition to the Procurement List.
Accordingly, the following product and service are added to the Procurement List:
On 7/27/2018 (83 FR 145), the Committee for Purchase From People Who Are Blind or Severely Disabled published notice of proposed deletions from the Procurement List.
After consideration of the relevant matter presented, the Committee has determined that the products and services listed below are no longer suitable for procurement by the Federal Government under 41 U.S.C. 8501-8506 and 41 CFR 51-2.4.
I certify that the following action will not have a significant impact on a substantial number of small entities. The major factors considered for this certification were:
1. The action will not result in additional reporting, recordkeeping or other compliance requirements for small entities.
2. The action may result in authorizing small entities to furnish the products and services to the Government.
3. There are no known regulatory alternatives which would accomplish the objectives of the Javits-Wagner-O'Day Act (41 U.S.C. 8501-8506) in connection with the products and services deleted from the Procurement List.
Accordingly, the following products and services are deleted from the Procurement List:
The Committee for Purchase From People Who Are Blind or Severely Disabled published a document in the
Committee for Purchase From People Who Are Blind or Severely Disabled.
Notice; corrections.
The Committee for Purchase From People Who Are Blind or Severely Disabled published a document in the
Also, concerning NSNs 5180-00-NIB-0025—Tool Kit, Refrigeration, Base and 5180-00-NIB-0026—Tool Kit, Refrigeration, Individual to the Procurement List for U.S. Army Contracting Command—Warren. The document corrects “the NSNs” information and Mandatory Source of Supply.
Comments must be received on or before September 23, 2018.
Michael R. Jurkowski, Telephone: (703) 603-2117.
In the
On page 42881, in the first column, correct the NSNs to read 5180-01-666-1184—Tool Kit, Refrigeration, Base and 5180-01-666-0751—Tool, Kit Refrigeration, Individual and correct Mandatory Source of Supply to read Wiscraft, Inc., Milwaukee, WI.
Bureau of Consumer Financial Protection.
Notice and request for comment.
In accordance with the Paperwork Reduction Act of 1995 (PRA), the Bureau of Consumer Financial Protection (Bureau) is proposing to revise an existing information collection titled, “Consumer Complaint Intake System Company Portal Boarding Form.”
Written comments are encouraged and must be received on or before October 1, 2018 to be assured of consideration.
Comments in response to this notice are to be directed towards OMB and to the attention of the OMB Desk Officer for the Bureau of Consumer Financial Protection. You may submit comments, identified by the title of the information collection, OMB Control Number (see below), and docket number (see above), by any of the following methods:
•
•
•
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In general, all comments received will become public records, including any personal information provided. Sensitive personal information, such as account numbers or Social Security numbers, should not be included.
Documentation prepared in support of this information collection request is available at
The Bureau issued a 60-day
General Counsel of the Department of Defense, Department of Defense.
Notice of federal advisory committee meeting.
The Department of Defense (DoD) is publishing this notice to announce that the following Federal Advisory Committee meeting of the Defense Advisory Committee on Investigation, Prosecution, and Defense of Sexual Assault in the Armed Forces will take place.
Open to the public, Friday, September 7, 2018 from 11:00 a.m. to 1:00 p.m.
One Liberty Center, 875 N Randolph Street, Suite 150, Arlington, Virginia 22203.
Dwight Sullivan, 703-695-1055 (Voice),
Due to circumstances beyond the control of the Department of Defense (DoD) and the Designated Federal Officer, the Defense Advisory Committee on Investigation, Prosecution, and Defense of Sexual Assault in the Armed Forces was unable to provide public notification required by 41 CFR 102-3.150(a) concerning its meeting on September 7, 2018. Accordingly, the Advisory Committee Management Officer for the Department of Defense, pursuant to 41 CFR 102-3.150(b), waives the 15-calendar day notification requirement.
This meeting is being held under the provisions of the Federal Advisory Committee Act (FACA) 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 102-3.140 and 102-3.150.
U.S. Army Corps of Engineers, DoD.
Notice.
The Kansas City and Omaha Districts of the U.S. Army Corps of Engineers (USACE), in cooperation with the U.S. Fish and Wildlife Service (USFWS), have developed the Missouri River Recovery Management Plan and Environmental Impact Statement (MRRMP-EIS). This document is a programmatic assessment of major federal actions necessary to avoid a finding of jeopardy to the pallid sturgeon (
Submit written comments on the final EIS and supporting documents on or before October 9, 2018.
Send written comments to U.S. Army Corps of Engineers, Omaha District, ATTN: CENWO-PM-AC—MRRMP-EIS, 1616 Capitol Ave., Omaha, NE 68102; attach comment letters via email at
Tiffany Vanosdall, Project Manager at 402-995-2695.
The USACE is issuing this notice pursuant to section 102(2)(c) of the National Environmental Policy Act of 1969 (NEPA), as amended (42 U.S.C. 4321
The draft MRRMP-EIS was released on December 23, 2016 and included a 122-day public comment period that ended on April 24, 2017. During that time USACE held six public meetings to solicit comments from the public. USACE analyzed the comments received from the public and considered them in preparation of the final MRRMP-EIS (Appendix K). The final MRRMP-EIS is available for public review until October 9, 2018. The USACE has also completed formal consultation with the USFWS under Section 7 of the ESA. A final Biological Assessment (BA) was completed by the USACE in October of 2017 and a Final BiOp was completed by the USFWS in April, 2018. The BiOp concludes that the proposed action described in the BA would not cause jeopardy for the least tern, piping plover, or pallid sturgeon. The preferred alternative in the Final EIS incorporates the proposed action described in the 2017 BA and incorporates the 2018 BiOp.
This EIS provides the necessary information for the public to fully evaluate a range of alternatives designed to meet the purpose and need of the MRRMP-EIS and to provide thoughtful and meaningful comment for the Agency's consideration. Six alternatives were carried forward for detailed evaluation in the MRRMP-EIS (the no-action alternative and five action alternatives). The following management actions were included in all six of the alternatives:
Under the no-action alternative, in addition to the actions common to all alternatives, the USACE would mechanically construct ESH at a rate of 164 acres per year in the Garrison and Gavins Point reaches and construct pallid early life stage habitat to achieve an average of 20 acres of shallow water habitat per river mile. The no-action alternative would also continue to implement the spring pulse included in the Master Manual.
Alternative 2 represents the USFWS's interpretation of the management actions that could be ultimately implemented as part of the 2003 Amended BiOp Reasonable and Prudent Alternative (RPA). In addition to the actions common to all alternatives, the USACE would mechanically construct ESH at a rate up to 1,331 acres per year in the Garrison, Fort Randall, Lewis and Clark Lake, and Gavins Point reaches and pallid early life stage habitat to achieve an average of 30 acres of shallow water habitat per river mile. Alternative 2 would also include a spring pallid flow release consisting of a bimodal pulse in March and May and a low summer flow.
Under Alternatives 3-6, the USACE would follow the processes and criteria in the SAMP that was developed based on the results of the effects analysis. The SAMP identifies the process and criteria to implement initial management actions, assess hypotheses, and introduce new management actions should they become necessary. Initial management actions include specific study efforts to fill data gaps in knowledge of the pallid sturgeon life cycle, creation of spawning habitat for pallid sturgeon to monitor effectiveness, and the construction of pallid early life stage habitat following the interception and rearing complex (IRC) concept identified in the effects analysis.
In addition to the actions common to Alternatives 3-6, Alternative 3 would include mechanical construction of ESH at an average rate of 332 acres per year when construction is needed in the Garrison, Fort Randall, and Gavins Point reaches. Alternative 3 would not implement the plenary spring pulse included in the Master Manual. However, as part of the SAMP the potential for a one-time spawning cue
In addition to the actions common to Alternatives 3-6, Alternative 4 would include mechanical construction of ESH at an average rate of 195 acres per year when construction is needed in the Garrison, Fort Randall, and Gavins Point reaches. Alternative 4 also includes implementation of a spring ESH creation release if System storage is at 42 MAF or greater on April 1, normal flows that could create 250 acres of ESH have not occurred in the previous four years, and downstream flow is below identified flood control constraints specific to this alternative.
In addition to the actions common to Alternatives 3-6, Alternative 5 would include mechanical construction of ESH at an average rate of 253 acres per year when construction is needed in the Garrison, Fort Randall, and Gavins Point reaches. Alternative 5 also includes implementation of a fall ESH creation release if System storage is at 54.5 MAF or greater on October 17, normal flows that could create 250 acres of ESH have not occurred in the previous four years, and downstream flow is below identified flood control constraints specific to this alternative.
In addition to the actions common to Alternatives 3-6, Alternative 6 would include mechanical construction of ESH at an average rate of 245 acres per year when construction is needed in the Garrison, Fort Randall, and Gavins Point reaches. Alternative 6 also includes implementation of a spawning cue release, attempted every 3 years, consisting of a bimodal pulse in March and May. These spawning cue releases would not be started or would be terminated whenever downstream flow is at identified flood control constraints specific to this alternative.
The final EIS evaluates the potential effects on the human environment associated with each of the above alternatives. Resources and uses evaluated include: River infrastructure and hydrological processes; pallid sturgeon; piping plover and interior least tern; fish and wildlife habitat; other special status species; water quality; air quality; cultural resources; land use and ownership; commercial sand and gravel dredging; flood risk management and interior drainage; hydropower; irrigation; navigation; recreation; thermal power; water supply; wastewater facilities; tribal interests (other); human health and safety; environmental justice; ecosystem services; and Mississippi River resources.
Based on projected impacts, the ability to meet the plan's purpose, need and species objectives, and other decision criteria, USACE has identified Alternative 3-Mechanical Construction as its preferred alternative. Importantly, Alternative 3 would be implemented under the science and adaptive management framework summarized in Chapter 4 of the MRRMP-EIS and detailed within the Science and Adaptive Management Plan (SAMP).
Department of Education (ED), Office of Elementary and Secondary Education (OESE).
Notice.
In accordance with the Paperwork Reduction Act of 1995, ED is proposing a new information collection.
Interested persons are invited to submit comments on or before October 1, 2018.
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 Melissa Siry, 202-260-0926.
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 Environmental Management, 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, September 19, 2018 8:30 a.m.-4:45 p.m., Thursday, September 20, 2018 8:30 a.m.-1:00 p.m.
Embassy Suites by Hilton Seattle Bellevue, 3225 158th Avenue SE, Bellevue, WA 98008.
Kristen Holmes, Federal Coordinator, Department of Energy Richland Operations Office, P.O. Box 550, H5-20, Richland, WA 99352; Phone: (509) 373-5803; or Email:
Office of Fossil Energy, Department of Energy.
Notice of Open Meeting.
This notice announces a meeting of the Methane Hydrate Advisory Committee. The Federal Advisory Committee Act requires that notice of these meetings be announced in the
Houston Airport Marriott at George Bush International, 18700 John F. Kennedy Blvd., Houston, TX, 77032.
Gabby Intihar, U.S. Department of Energy, Office of Oil and Natural Gas, 1000 Independence Avenue SW, Washington, DC 20585.
This is a supplemental notice in the above-referenced proceeding Rose Wind Holdings, 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 September 17, 2018.
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 website 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 the Commission received the following electric rate filings:
Take notice that the Commission received the following electric securities 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 August 17, 2018, Panhandle Eastern Pipe Line Company, LP (Panhandle), 1300 Main Street, Houston, Texas 77002, filed in Docket No. CP18-540-000, a Prior Notice Request pursuant to sections 157.205, and 157.216 of the Commission's regulations under the Natural Gas Act (NGA), and Panhandle's blanket certificate issued in Docket No. CP83-83-000, requesting approval to abandon by sale to ETC Field Services LLC, the Deer Loop Lateral Facilities, consisting of approximately 20.64 miles of 12.75-inch diameter pipeline and appurtenances, located in Carson, Hutchinson and Moore Counties, Texas (Deer Loop Lateral Abandonment Project).
The Deer Loop Lateral was originally constructed to transport high-pressure gas from Panhandle's Deer Compressor Station to its Sneed Compressor Station, allowing existing Deer to Sneed facilities to operate as a lower-pressure gathering system.
Any questions regarding this prior notice request may be directed to Blair Lichtenwalter, Senior Director, Certificates, Panhandle Eastern Pipe Line Company, LP, by phone at (713) 989-2605 or by email at
Any person or the Commission's staff may, within 60 days after issuance of the instant notice by the Commission, file pursuant to Rule 214 of the Commission's Procedural Rules (18 CFR 385.214) a motion to intervene or notice of intervention and pursuant to section 157.205 of the regulations under the NGA (18 CFR 157.205), a protest to the request. If no protest is filed within the time allowed therefore, the proposed activity shall be deemed to be authorized effective the day after the time allowed for filing a protest. If a protest is filed and not withdrawn within 30 days after the allowed time for filing a protest, the instant request shall be treated as an application for authorization pursuant to section 7 of the NGA.
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 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 EA.
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 commenters 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 commenters will not be required to serve copies of filed documents on all other parties. However, the non-party commenters, 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
This is a supplemental notice in the above-referenced proceeding Garwind, 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 September 17, 2018.
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 website 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
This is a supplemental notice in the above-referenced proceeding K&K Wind Enterprises, 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 September 17, 2018.
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 website 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
This is a supplemental notice in the above-referenced proceeding Bobilli BSS, 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 September 17, 2018.
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 website 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
This is a supplemental notice in the above-referenced proceeding of Enel Green Power Diamond Vista Wind Project, 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 September 17, 2018.
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 website 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 the Commission received the following electric corporate filings:
Take notice that the Commission received the following electric rate filings:
Take notice that the Commission received the following electric reliability 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 exempt wholesale generator filings:
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:
This is a supplemental notice in the above-referenced proceeding Adams Wind Farm, 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 September 17, 2018.
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 website 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 August 17, 2018, Texas Eastern Transmission, LP (Texas Eastern), 5400 Westheimer Court, Houston, Texas 77056-5310, filed in Docket No. CP18-541-000 a prior notice request pursuant to sections 157.205 and 157.208 of the Commission's regulations under the Natural Gas Act (NGA), and Texas Eastern's blanket certificate issued in Docket No. CP82-535-000, to construct its Rahway River Additional Pipe Replacement Project, in Woodbridge, New Jersey.
Specifically, Texas Eastern proposes to replace an additional approximately 400-foot segment of its new 20-inch-diameter Line 1 pipeline. In Docket No. CP17-496-000, Texas Eastern was authorized to replace a 1,250-foot segment of its Line 1 pipeline beneath the Rahway River (Rahway River Pipeline Replacement Project), which was designed to ensure the continued safe operation of Texas Eastern's pipeline facilities. The Project described herein would increase the total length of pipeline to be replaced to approximately 1,650 feet. Texas Eastern states that the 400-foot additional segment is located entirely within a warehouse parking lot. Texas Eastern avers that the additional activities will not cause a significant change to the estimated total cost of the Rahway River Pipeline Replacement Project in Docket No. CP17-496-000, all as more fully set forth in the application which is on file with the Commission
Any questions concerning this application may be directed to Lisa A. Connolly, Director, Rates and Certificates, Texas Eastern Transmission, LP, P.O. Box 1642, Houston, Texas 77251-1642, by telephone at (713) 627-4102, by fax at (713) 627-5947, or by email at
Any person or the Commission's staff may, within 60 days after issuance of the instant notice by the Commission, file pursuant to Rule 214 of the Commission's Procedural Rules (18 CFR 385.214) a motion to intervene or notice of intervention and pursuant to section 157.205 of the regulations under the NGA (18 CFR 157.205), a protest to the request. If no protest is filed within the time allowed therefore, the proposed activity shall be deemed to be authorized effective the day after the time allowed for filing a protest. If a protest is filed and not withdrawn within 30 days after the allowed time for filing a protest, the instant request shall be treated as an application for authorization pursuant to section 7 of the NGA.
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 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 EA.
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 commenters 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 commenters will not be required to serve copies of filed documents on all other parties. However, the non-party commenters, 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
This is a supplemental notice in the above-referenced proceeding SF Wind Enterprises, 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 September 17, 2018.
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 website 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
The staff of the Federal Energy Regulatory Commission (FERC or Commission) will prepare an environmental assessment (EA) that will discuss the environmental impacts of the D'Lo Natural Gas Storage Project Amendment involving construction and operation of facilities by D'Lo Gas
This notice announces the opening of the scoping process the Commission will use to gather input from the public and interested agencies about issues regarding the project. The National Environmental Policy Act (NEPA) requires the Commission to take into account the environmental impacts that could result from its action whenever it considers the issuance of a Certificate of Public Convenience and Necessity. NEPA also requires the Commission to discover concerns the public may have about proposals. This process is referred to as scoping. The main goal of the scoping process is to focus the analysis in the EA on the important environmental issues. By this notice, the Commission requests public comments on the scope of the issues to address in the EA. To ensure that your comments are timely and properly recorded, please submit your comments so that the Commission receives them in Washington, DC on or before 5:00 p.m. Eastern Time on September 26, 2018.
You can make a difference by submitting your specific comments or concerns about the project. Your comments should focus on the potential environmental effects, reasonable alternatives, and measures to avoid or lessen environmental impacts. Your input will help the Commission staff determine what issues they need to evaluate in the EA. Commission staff will consider and address all filed comments during the preparation of the EA.
If you sent comments on this project to the Commission before the opening of this docket on July 13, 2018, you will need to file those comments in Docket No. CP18-524-000 to ensure they are considered as part of this proceeding.
This notice is being sent to the Commission's current environmental mailing list for this project. State and local government representatives should notify their constituents of this proposed project and encourage them to comment on their areas of concern.
If you are a landowner receiving this notice, a pipeline company representative may contact you about the acquisition of an easement to construct, operate, and maintain the proposed facilities. The company would seek to negotiate a mutually acceptable easement agreement. You are not required to enter into an agreement. However, if the Commission approves the project, that approval conveys with it the right of eminent domain. Therefore, if you and the company do not reach an easement agreement, the pipeline company could initiate condemnation proceedings in court. In such instances, compensation would be determined by a judge in accordance with state law.
DGS provided landowners with a fact sheet prepared by the FERC entitled An Interstate Natural Gas Facility On My Land? What Do I Need To Know? This fact sheet addresses a number of typically asked questions, including the use of eminent domain and how to participate in the Commission's proceedings. It is also available for viewing on the FERC website (
For your convenience, there are three methods you can use to submit your comments to the Commission. The Commission encourages electronic filing of comments and has staff available to assist you at (866) 208-3676 or
(1) You can file your comments electronically using the
(2) You can file your comments electronically by using the
(3) You can file a paper copy of your comments by mailing them to the following address. Be sure to reference the project docket number (CP18-524-000) with your submission:
Kimberly D. Bose, Secretary, Federal Energy Regulatory Commission, 888 First Street NE, Room 1A, Washington, DC 20426.
The FERC issued a Certificate for the original D'Lo Gas Storage Project on September 6, 2012 in Docket No. CP12-39-000. DGS proposes to amend the originally certificated project design, as described below. The D'Lo Gas Storage Project would provide about 1.2 billion cubic feet (Bcf) per day of withdrawal and 0.59 Bcf per day of injection capacity. According to DGS, its project would help meet the growing demand for firm and interruptible high deliverability natural gas storage services to support deliveries of natural gas to widely variable electric power generation loads, and to provide services to growing local distribution companies and other markets that require highly reliable natural gas service in Mississippi, and the Northeastern, mid-Atlantic, Southeastern, and Florida regions.
DGS is proposing the following amendments to the originally certificated project design:
• Elimination of the Gulf South Interconnect Lateral and Gulf South Meter Station facilities; and
• relocation of Primary Source Water Wells #2 and #4 and Primary Brine Disposal Wells #2 and #4 approximately 0.4 mile south of their originally proposed locations.
The revised scope of the total project includes:
• The solution mining of three salt dome caverns with a designed total working gas volume of 8.0 Bcf per cavern;
• a new solution mining facility site having injection and withdrawal capacity of 4,000-8,000 gallons per minute (gpm);
• a new compressor station with four 8,000 horsepower (hp) and one 4,735 hp Caterpillar gas engine driven compressors, totaling 36,735 hp;
• the drilling and completion of four primary and three secondary source water wells, each having a total production capability of 1,000 gpm;
• the drilling and completion of four primary and one secondary brine disposal wells, each having injection capability of 1,000 gpm;
• 4.0 miles of 20-inch-diameter source water pipelines;
• 4.0 miles of 20-inch-diameter brine disposal pipelines;
• 0.2 mile of 24-inch-diameter natural gas pipeline from the compressor and solution mining facility sites to Cavern Well #3;
• 0.4 mile of 30-inch-diameter natural gas pipeline with an interconnect and meter station to Boardwalk Pipeline Company;
• 0.8 mile of 24-inch-diameter natural gas pipeline with an interconnect and meter station to Southern Natural Gas Pipeline Company;
• 3.2 miles of 30-inch-diameter natural gas pipeline with an
• a new 12-inch-diameter tap and interconnect and meter station to Southcross Energy; and
• the widening and improvement of 3.5 miles of existing access roads, and construction of 0.8 mile of new access roads for construction, operations, and maintenance of the proposed facilities.
The general location of the project facilities is shown in appendix 1.
Construction of the proposed facilities would disturb about 160.3 acres of land for the aboveground facilities and pipelines. Following construction, DGS would maintain about 113.8 acres for permanent operation of the project's facilities; the remaining acreage would be restored and revert to former uses. The proposed changes presented above would reduce surface impacts from the original project by approximately 14.1 acres. DGS owns and/or controls all areas of the project that would be permanently impacted.
The EA will discuss impacts that could occur as a result of the construction and operation of the proposed project under these general headings:
• Geology and soils;
• land use;
• water resources, fisheries, and wetlands;
• cultural resources;
• vegetation and wildlife;
• air quality and noise;
• endangered and threatened species;
• public safety; and
• cumulative impacts
Commission staff will also evaluate reasonable alternatives to the proposed project or portions of the project, and make recommendations on how to lessen or avoid impacts on the various resource areas.
The EA will present Commission staffs' independent analysis of the issues. The EA will be available in the public record through eLibrary.
With this notice, the Commission is asking agencies with jurisdiction by law and/or special expertise with respect to the environmental issues of this project to formally cooperate in the preparation of the EA.
In accordance with the Advisory Council on Historic Preservation's implementing regulations for section 106 of the National Historic Preservation Act, the Commission is are using this notice to initiate consultation with the applicable State Historic Preservation Office (SHPO), and to solicit their views and those of other government agencies, interested Indian tribes, and the public on the project's potential effects on historic properties.
The environmental mailing list includes federal, state, and local government representatives and agencies; elected officials; environmental and public interest groups; Native American Tribes; other interested parties; and local libraries and newspapers. This list also includes all affected landowners (as defined in the Commission's regulations) who are potential right-of-way grantors, whose property may be used temporarily for project purposes, or who own homes within certain distances of aboveground facilities, and anyone who submits comments on the project. Commission staff will update the environmental mailing list as the analysis proceeds to ensure that information related to this environmental review is sent to all individuals, organizations, and government entities interested in and/or potentially affected by the proposed project.
As stated above, the EA will be available in the public record through the Commission's eLibrary, under the Docket Number CP18-524-000.
Additional information about the project is available from the Commission's Office of External Affairs, at (866) 208-FERC, or on the FERC website at
In addition, the Commission offers a free service called eSubscription which allows you to keep track of all formal issuances and submittals in specific dockets. This can reduce the amount of time you spend researching proceedings by automatically providing you with notification of these filings, document summaries, and direct links to the documents. Go to
Finally, public sessions or site visits will be posted on the Commission's calendar located at
This is a supplemental notice in the above-referenced proceeding Rose Creek Wind, 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 September 17, 2018.
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 website 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
Environmental Protection Agency (EPA).
Notice.
The Environmental Protection Agency (EPA) has submitted an information collection request (ICR), Aircraft Engines—Supplemental Information Related to Exhaust Emissions (EPA ICR Number 2427.04, OMB Control Number 2060-0680) to the Office of Management and Budget (OMB) for review and approval in accordance with the Paperwork Reduction Act. This is a proposed extension of the ICR, which is currently approved through September 30, 2018. Public comments were previously requested via the
Additional comments may be submitted on or before October 1, 2018.
Submit your comments, referencing Docket ID Number EPA-HQ-OAR-2016-0546, to (1) EPA online using
EPA's policy is that all comments received will be included in the public docket without change including any personal information provided, unless the comment includes profanity, threats, information claimed to be Confidential Business Information (CBI) or other information whose disclosure is restricted by statute.
Cullen Leggett, Office of Transportation and Air Quality, Office of Air and Radiation, Environmental Protection Agency; telephone number: (734) 214-4514; fax number: (734) 214-4816; email address:
Supporting documents, which explain in detail the information that the EPA will be collecting, are available in the public docket for this ICR. The docket can be viewed online at
Environmental Protection Agency (EPA).
Notice.
The Environmental Protection Agency (EPA) has submitted an information collection request (ICR), NSPS for Sulfuric Acid Plants (EPA ICR No. 1057.14, OMB Control No. 2060-0041), to the Office of Management and Budget (OMB) for review and approval in accordance with the Paperwork Reduction Act. This is a proposed extension of the ICR, which is currently approved through September 30, 2018. Public comments were previously requested, via the
Additional comments may be submitted on or before October 1, 2018.
Submit your comments, referencing Docket ID Number EPA-HQ-OECA-2014-0035, to: (1) EPA online using
EPA's policy is that all comments received will be included in the public docket without change, including any personal information provided, unless the comment includes profanity, threats, information claimed to be Confidential Business Information (CBI), or other information whose disclosure is restricted by statute.
Patrick Yellin, Monitoring, Assistance, and Media Programs Division, Office of Compliance, Mail Code 2227A, Environmental Protection Agency, 1200 Pennsylvania Ave. NW, Washington, DC 20460; telephone number: (202) 564-2970; fax number: (202) 564-0050; email address:
Supporting documents, which explain in detail the information that the EPA will be collecting, are available in the public docket for this ICR. The docket can be viewed online at
In general, all NSPS standards require initial notifications, performance tests, and periodic reports by the owners/operators of the affected facilities. They are also required to maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of an affected facility, or any period during which the monitoring system is inoperative. These notifications, reports, and records are essential in determining compliance, and are required of all affected facilities subject to NSPS.
Environmental Protection Agency (EPA).
Notice.
The Environmental Protection Agency (EPA) has submitted an information collection request (ICR), Producers, Registrants and Applicants of Pesticides and Pesticide Devices under Section 8 of the Federal Insecticide, Fungicide, and Rodenticide Act (EPA ICR Number 0143.13, OMB Control Number 2070-0028), to the Office of Management and Budget (OMB) for review and approval in accordance with the Paperwork Reduction Act. This is a proposed extension of the ICR, which is currently approved through September 30, 2018. Public comments were previously requested via the
Additional comments may be submitted on or before October 1, 2018.
Submit your comments, referencing Docket ID Number EPA-HQ-OECA-2017-0640 to (1) EPA online using
EPA's policy is that all comments received will be included in the public docket without change including any personal information provided, unless the comment includes profanity, threats, information claimed to be Confidential Business Information (CBI) or other information whose disclosure is restricted by statute.
Michelle Stevenson, Office of Compliance, Monitoring, Assistance, and Media Programs Division, Pesticides, Waste & Toxics Branch (2225A), Environmental Protection Agency, 1200 Pennsylvania Ave. NW, Washington, DC 20460; telephone number: (202) 564-4203; fax number: (202) 564-0085; email:
Supporting documents, which explain in detail the information that the EPA will be collecting, are available in the public docket for this ICR. The docket can be viewed online at
Environmental Protection Agency (EPA).
Notice.
The Environmental Protection Agency (EPA) is interested in the views of the public on possible approaches to updating the National Pollutant Discharge Elimination System (NPDES) regulations related to the management of peak wet weather flows at Publicly Owned Treatment Works (POTWs) treatment plants serving separate sanitary sewer collection systems. Consequently, EPA is inviting interested members of the public to three planned listening sessions on: October 16, 2018 at EPA Headquarters in Washington, DC, October 24, 2018 at EPA Region 7 in Lenexa, Kansas, and October 30, 2018 to be held online. EPA welcomes oral or written information at the listening sessions as well as any other information the public may wish to provide EPA through the docket (Docket ID No. EPA-HQ-OW-2018-0420).
The in-person listening sessions will be held at EPA Headquarters in Washington, DC on October 16, 2018 from 9:00 a.m. to 2:00 p.m. EDT; and in EPA Region 7 in Lenexa, Kansas on October 24, 2018 from 9:00 a.m. to 2:00 p.m. CDT. In addition to the in-person listening sessions, EPA will hold an online listening session on October 30, 2018 from 11:00 a.m. to 4:00 p.m. EDT.
For those who intend to submit written statements to the docket, EPA is asking that this information be provided before October 31, 2018.
The in-person listening sessions will be held at the following locations:
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The online listening session will be accessible though
Jamie Piziali, Water Permits Division, Office of Water, Environmental Protection Agency, 1200 Pennsylvania Avenue NW, Washington, DC 20460; telephone number: 202-564-1709; or email:
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Prior to each listening session, EPA will post any relevant materials to the following website:
EPA is providing the following background information to assist the public in preparing for the listening sessions. Under the Clean Water Act (CWA), municipal sewage treatment plants or Publicly Owned Treatment Works (POTWs) treatment plants are required to comply with prescribed restrictions on their discharges to a water of the United States. Specifically, each POTW must obtain an NPDES permit that will require, at a minimum, that the treatment plant's discharge meet effluent limitations for secondary treatment. See CWA § 1311(b)(1)(B) and § 1342(a), 40 CFR 133 and 40 CFR 122.44(a)(1). The permit will also require meeting any more stringent effluent limitations that are necessary to meet applicable water quality standards. See CWA § 1311(b)(1)(C), § 1342(a), and 40 CFR 122.44(d). The permit will also require the POTW operator to comply with other terms and conditions based on the NPDES regulations at 40 CFR 122. These include, for example, requirements regarding monitoring and reporting of discharges and proper operation and maintenance of POTW facilities and systems of treatment.
Many sewage treatment processes may be used to comply with these effluent requirements. Most municipalities use a series of unit processes to treat wastewater prior to discharge including the following:
• Preliminary treatment or screening to remove large solids,
• primary clarification (or preliminary sedimentation) to remove floating and settleable solids,
• biological treatment (also referred to as secondary treatment) to remove biodegradable organic pollutants and suspended solids, and
• disinfection to deactivate pathogens.
Some facilities also provide more advanced treatment, which is designed to reduce constituents, such as nitrogen and phosphorus, that are not removed in any significant quantity by traditional biological treatment processes.
Sanitary sewer collection systems are designed to remove wastewater from homes and other buildings and convey it to a wastewater treatment plant. The collection system is a critical element in the successful performance of the POTW's wastewater treatment operation. Collection systems are designed in one of two ways. Combined sewer systems are designed to collect both stormwater and sanitary wastewater for delivery to the treatment plant. By contrast, separate sanitary sewers are designed to carry only sanitary wastewater (separate sanitary sewers typically are built with some allowance, however, for higher flows that occur during storm events in order to handle minor and non-excessive amounts of stormwater or groundwater that enter the system through infiltration and inflow or “I/I”). EPA notes that, at this time, it contemplates the scope of the rulemaking would be limited to peak flows at POTWs with separate sanitary sewer systems.
Significant increases in flows at a treatment facility can create operational challenges and potentially adversely affect the treatment efficiencies. Biological treatment components at treatment plants are particularly vulnerable to high-volume peak flows. Where peak influent flows during periods of wet weather exceed the treatment capacity of existing biological or advanced treatment units, POTWs must consider ways in which to prevent damage to their treatment plant, while maintaining effective operation of the system to meet applicable NPDES permit limitations. Under these conditions, POTW operators use several different strategies which may include a combination of alternative treatment approaches, storage, and sewer maintenance and rehabilitation work to minimize the amount of stormwater that enters the collection system through I/I.
Among the peak flow management approaches that have been used or considered are those involving the diversion of a portion of the peak flows around biological or advanced treatment units. The diverted flow is then recombined with flows from the biological treatment units. Other alternatives include the installation of various treatment processes at the POTW that supplement the plant's ability to process and treat peak flows. Refer to EPA's
POTWs with separate sanitary sewer systems can also lessen the impact of peak flows by implementing a variety of strategies to minimize the introduction of stormwater into the collection system. While virtually every separate sanitary sewer system has some groundwater infiltration and stormwater-derived I/I, it may be considered excessive when it is the cause of overflows or causes disruptions in the treatment system. POTWs with excessive I/I have a number of different methods for identifying the largest sources of I/I in their sewer system. These include system mapping, flow monitoring, conducting smoke or dye tests, sensor technology, and using optical devices to view sections of the system. Developing plans for correcting and rehabilitating the highest priority sources of I/I into the collection system may involve such strategies as repairing manholes, replacing and repairing private building lateral pipes, ensuring building downspouts are not connected to the sewer system, sealing sewer joints, inserting sewer liners, or even replacing sections of the sewer line. Other strategies may focus on maximizing existing collection system capacity through real-time controls to optimize flows within the system, or building additional storage within the collection system or treatment plant.
EPA acknowledges the significant expertise that exists among states, tribes, POTWs and municipal officials, engineering firms, public health agencies, and the public related to these issues. These listening sessions are designed to take advantage of this information from a variety of perspectives to help provide a complete picture of the considerations that should go into any rulemaking to address permitting requirements for the management of peak flows at POTWs with separate sanitary sewer systems.
Interested members of the public who plan to provide oral or written testimony at the listening sessions, or to submit written material to EPA separately as detailed in the instructions provided in the
• What strategies have you found to be successful in reducing peak flow volumes at the POTW treatment plant?
• What permitting or other regulatory approaches are you aware of that in your opinion provide a good basis for any rulemaking in this area?
• What treatment technologies have POTWs with separate sanitary sewer systems used successfully to manage peak excess flows during wet weather? How effective are these technologies at meeting effluent limitations? What are examples of technologies addressing other pollutants not typically subject to discharge requirements in NPDES permits (
• What are your specific suggestions regarding conditions that could be included in NPDES permits to allow diversions of some peak flows around biological treatment units to protect the treatment plant? Considerations could include:
Clean Water Act, 33 U.S.C. 1251
Office of Federal Activities, EPA.
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:
Environmental Protection Agency (EPA).
Notice.
EPA has received applications to register pesticide products containing active ingredients not included in any currently registered pesticide products. Pursuant to the Federal Insecticide, Fungicide, and Rodenticide Act (FIFRA), EPA is hereby providing notice of receipt and opportunity to comment on these applications.
Comments must be received on or before October 1, 2018.
Submit your comments, identified by the Docket Identification (ID) Number and the File Symbol of interest as shown in the body of this document, by one of the following methods:
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Additional instructions on commenting or visiting the docket, along with more information about dockets generally, is available at
Robert McNally, Biopesticides and Pollution Prevention Division (7511P), Office of Pesticide Programs, Environmental Protection Agency, 1200 Pennsylvania Ave. NW, Washington, DC 20460-0001; main telephone number: (703) 305-7090; email address:
You may be potentially affected by this action if you are an agricultural producer, food manufacturer, or pesticide manufacturer. 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:
• Crop production (NAICS code 111).
• Animal production (NAICS code 112).
• Food manufacturing (NAICS code 311).
• Pesticide manufacturing (NAICS code 32532).
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EPA has received applications to register pesticide products containing active ingredients not included in any currently registered pesticide products. Pursuant to the provisions of FIFRA section 3(c)(4) (7 U.S.C. 136a(c)(4)), EPA is hereby providing notice of receipt and opportunity to comment on these applications. Notice of receipt of these applications does not imply a decision by the Agency on these applications.
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7 U.S.C. 136
Environmental Protection Agency (EPA).
Notice.
The Environmental Protection Agency (EPA) has submitted an information collection request (ICR), “Cross-State Air Pollution Rule and Texas SO
Additional comments may be submitted on or before October 1, 2018.
Submit your comments, referencing Docket ID Number No. EPA-HQ-OAR-2018-0209, online using
EPA's policy is that all comments received will be included in the public docket without change including any personal information provided, unless the comment includes profanity, threats, information claimed to be Confidential Business Information (CBI) or other information whose disclosure is restricted by statute.
Karen VanSickle, Clean Air Markets Division, Office of Air and Radiation, (6204M), Environmental Protection Agency, 1200 Pennsylvania Ave. NW, Washington, DC 20460; telephone number: 202-343-9220; fax number: 202-343-2361; email address:
Supporting documents, which explain in detail the information that the EPA will be collecting, are available in the public docket for this ICR. The docket can be viewed online at
The companies listed in this notice have applied to the Board for approval, pursuant to the Bank Holding Company Act of 1956 (12 U.S.C. 1841
The applications listed below, as well as other related filings required by the Board, are available for immediate inspection at the Federal Reserve Bank indicated. The applications will also be available for inspection at the offices of the Board of Governors. Interested persons may express their views in writing on the standards enumerated in the BHC Act (12 U.S.C. 1842(c)). If the proposal also involves the acquisition of a nonbanking company, the review also includes whether the acquisition of the nonbanking company complies with the standards in section 4 of the BHC Act (12 U.S.C. 1843). Unless otherwise noted, nonbanking activities will be conducted throughout the United States.
Unless otherwise noted, comments regarding each of these applications must be received at the Reserve Bank indicated or the offices of the Board of Governors not later than September 27, 2018.
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The notificants listed below have applied under the Change in Bank Control Act (12 U.S.C. 1817(j)) and § 225.41 of the Board's Regulation Y (12 CFR 225.41) to acquire shares of a bank or bank holding company. The factors that are considered in acting on the notices are set forth in paragraph 7 of the Act (12 U.S.C. 1817(j)(7)).
The notices are available for immediate inspection at the Federal Reserve Bank indicated. The notices also will be available for inspection at the offices of the Board of Governors. Interested persons may express their views in writing to the Reserve Bank indicated for that notice or to the offices of the Board of Governors. Comments must be received not later than September 19, 2018.
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In accordance with the Paperwork Reduction Act of 1995, the Centers for Disease Control and Prevention (CDC) has submitted the information collection request titled Monitoring Breastfeeding-Related Maternity Care—U.S. hospitals to the Office of Management and Budget (OMB) for review and approval. CDC previously published a “Proposed Data Collection Submitted for Public Comment and Recommendations” notice on November 22, 2017, to obtain comments from the public and affected agencies. CDC received 12 comments related to the previous notice. This notice serves to allow an additional 30 days for public and affected agency comments.
CDC will accept all comments for this proposed information collection project. The Office of Management and Budget is particularly interested in comments that:
(a) Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(b) Evaluate the accuracy of the agencies estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
(c) Enhance the quality, utility, and clarity of the information to be collected;
(d) Minimize the burden of the collection of information on those who are to respond, including, through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
(e) Assess information collection costs.
To request additional information on the proposed project or to obtain a copy of the information collection plan and instruments, call (404) 639-7570 or send an email to
Monitoring Breastfeeding-Related Maternity Care—U.S. Hospitals (OMB Control No. 0920-0743, Exp. 9/30/2016)—Reinstatement with Change—Division of Nutrition, Physical Activity, and Obesity, National Center for Chronic Disease Prevention and Health Promotion (NCCDPHP), Centers for Disease Control and Prevention (CDC).
Substantial evidence demonstrates the social, economic, and health benefits of breastfeeding for both the mother and infant as well as for society in general. Breastfeeding mothers have lower risks of breast and ovarian cancers and type 2 diabetes, and breastfeeding better protects infants against infections, chronic diseases like diabetes and obesity, and even childhood leukemia and sudden infant death syndrome (SIDS). However, the groups that are at higher risk for diabetes, obesity, and poor health overall persistently have the lowest breastfeeding rates.
Health professionals recommend at least 12 months of breastfeeding, and Healthy People 2020 establishes specific national breastfeeding goals. In addition to increasing overall rates, a significant public health priority in the United States is to reduce variation in breastfeeding rates across population subgroups. Although CDC surveillance data indicate that breastfeeding initiation rates in the United States are climbing, rates for duration and exclusivity continue to lag, and significant disparities persist between African American and white women in breastfeeding rates.
The health care system is one of the most important and effective settings to improve breastfeeding. Recognition of the hospital stay as a crucial influence in later breastfeeding outcomes led to the addition of two objectives in Healthy People 2020 to allow national monitoring of improvements in support for breastfeeding during this time. In 2007, CDC conducted the first national survey of Maternity Practices in Infant Nutrition and Care (known as the mPINC Survey) in health care facilities (hospitals and free-standing childbirth centers). This survey was designed to provide baseline information and to be repeated every two years. The survey was conducted again in 2009, 2011, 2013, and 2015. The survey inquired about patient education and support for breastfeeding throughout the maternity stay as well as staff training and maternity care policies.
Prior to the fielding of the 2009 iteration, CDC was requested to provide a report to OMB on the results of the 2007 collection. In this report, CDC provided survey results by geographic and demographic characteristics and a summary of activities that resulted from the survey. A summary of mPINC findings was also the anchor of all activities related to the CDC August 2011 Vital Signs activity, marking the first time that CDC highlighted improving hospital maternity practices as the CDC-wide public health priority. A summary of mPINC findings provided the basis of the CDC October 2015 Vital Signs report, which updated the 2011 Vital Signs report and concluded that although maternity care policies and practices supportive of breastfeeding are improving nationally; more work is needed to ensure all women receive optimal breastfeeding support during the birth hospitalization.
The planned methodology for the 2018 and 2020 national survey of Maternity Practices in Infant Nutrition and Care (mPINC) will closely match that of the previously administered mPINC surveys in 2007, 2009, 2011, 2013, and 2015. Changes described in this Reinstatement with change include: (1) Deployment of 2018 and 2020 Surveys; (2) data collection via web-survey only (no paper surveys); (3) surveying hospitals only (not birth centers); (4) requesting contact information for two individuals per facility (previously only one); (5) an updated American Hospital Association (AHA) database will be acquired to identify hospitals not currently on the list for recruitment in the 2018 survey. This process will not occur for the 2020 survey, but additional hospitals identified from the new database for 2018 will be included in the 2020 survey; (6) 2018 and 2020 survey content has been updated.
A major strength of the mPINC survey is its structure as an ongoing national census, which does not employ sampling methods. Facilities are identified by using the American Hospital Association (AHA) Annual Survey of Hospitals. Facilities that will be invited to participate in the survey include hospitals that participated in previous iterations and those that were invited but did not participate in the previous iterations, as well as those that have become eligible since the most recent mPINC survey. All hospitals with ≥1 registered maternity bed will be screened via a brief phone call to assess their eligibility, identify additional satellite locations, and identify the appropriate point of contact. The high response rates to the previous iterations of the mPINC survey (82-83% in 2007, 2009, 2011, 2013, and 2015) indicate that the methodology is appropriate and also reflects high interest among the study population.
As with the initial surveys, a major goal of the 2018 and 2020 follow-up surveys is to be fully responsive to hospitals' needs for information and technical assistance. CDC will provide direct feedback to hospital respondents in a customized benchmark report of their results. CDC will use information from the mPINC surveys to identify, document, and share information related to incremental changes in practices and care processes over time at the hospital, state, and national levels. Data are also used by researchers to better understand the relationships between hospital characteristics, maternity-care practices, state level factors, and breastfeeding initiation and continuation rates. Participation in the survey is voluntary, and responses may be submitted through a Web-based system. The total estimated annual Burden Hours are 855. There are no costs to respondents other than their time.
Centers for Disease Control and Prevention (CDC), Department of Health and Human Services (HHS).
Notice with comment period.
The Centers for Disease Control and Prevention (CDC), as part of its continuing effort to reduce public burden and maximize the utility of government information, invites the general public and other Federal agencies the opportunity to comment on a proposed and/or continuing information collection, as required by the Paperwork Reduction Act of 1995. This notice invites comment on a proposed information collection project titled Pregnancy Risk Assessment Monitoring System (PRAMS). PRAMS provides an important supplement to vital records data by providing state-specific information not available through birth certificate data on maternal behaviors and experiences before, during and after pregnancy on health conditions, prenatal care, postpartum care, access to care, and health insurance status.
CDC must receive written comments on or before October 30, 2018.
You may submit comments, identified by Docket No. CDC-201x-xxxx by any of the following methods:
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To request more information on the proposed project or to obtain a copy of the information collection plan and instruments, contact Jeffrey M. Zirger, Information Collection Review Office, Centers for Disease Control and Prevention, 1600 Clifton Road NE, MS-D74, Atlanta, Georgia 30329; phone: 404-639-7570; Email:
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. In addition, the PRA also requires Federal agencies to provide a 60-day notice in the
The OMB is particularly interested in comments that will help:
1. Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
2. Evaluate the accuracy of the agency's estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
3. Enhance the quality, utility, and clarity of the information to be collected; and
4. Minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
5. Assess information collection costs.
The Pregnancy Risk Assessment Monitoring System (PRAMS)—Existing Collection in Use without an OMB Control Number—National Center for Chronic Disease Prevention and Health Promotion (NCCDPHP), Centers for Disease Control and Prevention (CDC).
The Centers for Disease Control and Prevention (CDC) seeks OMB approval to collect information through the Pregnancy Risk Assessment Monitoring System (PRAMS) for three years as a generic clearance. OMB approval for new modules will be submitted through the part of generic clearance mechanism.
PRAMS supplements vital records data by providing state-specific information on maternal behaviors and experiences before, during and after pregnancy. Every month, in each participating state, a sample of women who have recently given birth to a live born or stillborn infant is selected from birth certificates or fetal death files. The sample is stratified based on the state's population of interest to ensure high-risk populations are represented in the data. PRAMS is a state customized mail and telephone survey conducted in 51 sites and covers 83% of all live births in the United States. Information is collected by self-administered mail survey with telephone follow-up for non-responders. Because PRAMS uses standardized data collection methods, it allows data to be compared among states.
The PRAMS survey instrument is based on a core set of questions common across all states. Core questions request information that is not available from vital records; information about health conditions, prenatal care, postpartum care, access to care, or health insurance status; information about contraception, health habits or risk behaviors; and information about other topics such as breastfeeding. In addition, CDC provides participating states with standard questions from optional modules that states may use to customize survey content for their specific needs at the beginning of each Phase of data collection. In addition, on occasion, states may be funded to address emerging topics of interest to collect supplemental data on optional modules of interest. These questions can be used to address state-specific priorities and special topics such as, for example, substance use, including prescription and illicit opioid use, disease epidemics, or other topics related to healthy pregnancy; these supplements can be administered to women identified in the usual manner or via hospital records. States not intending to implement the survey on an ongoing basis, can instead employ a point-in-time survey. Because PRAMS infrastructure was developed to access a specific and vulnerable subpopulation, the PRAMS infrastructure can be
The burden estimate for PRAMS includes two types of information collection: (1) Information collection associated with the PRAMS core questions and predetermined standard questions from optional modules, and (2) information collection associated with optional modules for emerging issues. Participation is voluntary and there are no costs to respondents other than their time.
In accordance with the Paperwork Reduction Act of 1995, the Centers for Disease Control and Prevention (CDC) has submitted the information collection request titled Focus Group Testing to Effectively Plan and Tailor Cancer Prevention and Control Communication Campaigns to the Office of Management and Budget (OMB) for review and approval. CDC previously published a “Proposed Data Collection Submitted for Public Comment and Recommendations” notice on December 13, 2017 to obtain comments from the public and affected agencies. CDC did not receive comments related to the previous notice. This notice serves to allow an additional 30 days for public and affected agency comments.
CDC will accept all comments for this proposed information collection project. The Office of Management and Budget is particularly interested in comments that:
(a) Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(b) Evaluate the accuracy of the agencies estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
(c) Enhance the quality, utility, and clarity of the information to be collected;
(d) Minimize the burden of the collection of information on those who are to respond, including, through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
(e) Assess information collection costs.
To request additional information on the proposed project or to obtain a copy of the information collection plan and instruments, call (404) 639-7570 or send an email to
Focus Group Testing to Effectively Plan and Tailor Cancer Prevention and Control Communication Campaigns—(OMB No. 0920-0800, exp. 12/31/2017)—Reinstatement without Change—National Center for Chronic Disease Prevention and Health Promotion (NCCDPHP), Centers for Disease Control and Prevention (CDC).
CDC requests a reinstatement of the information collection with OMB Control Number 0920-0800. The mission of the CDC's Division of Cancer Prevention and Control (DCPC) is to reduce the burden of cancer in the United States through cancer prevention, reduction of risk, early detection, better treatment, and improved quality of life for cancer survivors. Toward this end, the DCPC supports the scientific development and implementation of various health communication campaigns with an emphasis on specific cancer burdens.
This process requires testing of messages, concepts, and materials prior to their final development and dissemination, as described in the second step of the health communication process. The health communication process is a scientific model developed by the U.S. Department of Health and Human Services' National Cancer Institute to guide sound campaign development. The communication literature supports various data collection methods, one of which is focus groups, to conduct credible formative, concept, message, and materials testing. The purpose of focus groups is to ensure that the public and other key audiences, like health professionals, clearly understand cancer-specific information and concepts, are motivated to take the desired action, and do not react negatively to the messages. CDC is currently approved to collect information needed to plan and tailor cancer communication campaigns (OMB No. 0920-0800, exp. 12/31/2017), and seeks OMB approval to reinstate this generic clearance.
Information collection will involve focus groups to assess numerous
DCPC plans to conduct or sponsor up to 80 focus groups per year over a three-year period. An average of 10 respondents will participate in each focus group discussion. DCPC has developed a set of example questions that can be used to develop a discussion guide for each focus group activity. The average burden for response for each focus group will be two hours. DCPC has also developed a set of example questions that can be tailored to screen for targeted groups of respondents. The average burden per response for screening and recruitment is three minutes. A separate information collection request will be submitted to OMB for approval of each focus group activity. The request will describe the purpose of the activity and include the customized information collection instruments.
OMB approval is requested for three years. There are no changes to information collection purpose or methodology. Annual estimated Burden Hours are 1,680. Participation is voluntary and there are no costs to respondents except their time.
Centers for Medicare & Medicaid Services (CMS), HHS.
Notice.
This notice announces the next meeting of the Advisory Panel on Outreach and Education (APOE) (the Panel) in accordance with the Federal Advisory Committee Act. The Panel advises and makes recommendations to the Secretary of the U.S. Department of Health and Human Services (HHS) and the Administrator of the Centers for Medicare & Medicaid Services (CMS) on opportunities to enhance the effectiveness of consumer education strategies concerning CMS programs, initiatives and priorities. This meeting is open to the public.
Lynne Johnson, Acting Designated Federal Official, Office of Communications, CMS, 7500 Security Boulevard, Mail Stop S1-05-06, Baltimore, MD 21244-1850, 410-786-0090, email
The Advisory Panel for Outreach and Education (APOE) (the Panel) is governed by the provisions of Federal Advisory Committee Act (FACA) (Pub. L. 92-463), as amended (5 U.S.C. Appendix 2), which sets forth standards for the formation and use of federal advisory committees. The Panel is authorized by section 1114(f) of the Social Security Act (42 U.S.C. 1314(f)) and section 222 of the Public Health Service Act (42 U.S.C. 217a).
The Secretary of the U.S. Department of Health and Human Services (HHS) (the Secretary) signed the charter establishing the Citizen's Advisory
The Medicare Modernization Act of 2003 (MMA) (Pub. L. 108-173) expanded the existing health plan options and benefits available under the M+C program and renamed it the Medicare Advantage (MA) program. We have had substantial responsibilities to provide information to Medicare beneficiaries about the range of health plan options available and better tools to evaluate these options. The successful MA program implementation required CMS to consider the views and policy input from a variety of private sector constituents and to develop a broad range of public-private partnerships.
In addition, Title I of the MMA authorized the Secretary and the Administrator of CMS (by delegation) to establish the Medicare prescription drug benefit. The drug benefit allows beneficiaries to obtain qualified prescription drug coverage. In order to effectively administer the MA program and the Medicare prescription drug benefit, we have substantial responsibilities to provide information to Medicare beneficiaries about the range of health plan options and benefits available, and to develop better tools to evaluate these plans and benefits.
The Affordable Care Act (Patient Protection and Affordable Care Act, Pub. L. 111-148, and Health Care and Education Reconciliation Act of 2010, Pub. L. 111-152) expanded the availability of other options for health care coverage and enacted a number of changes to Medicare as well as to Medicaid and the Children's Health Insurance Program (CHIP). Qualified individuals and qualified employers are now able to purchase private health insurance coverage through a competitive marketplace, called an Affordable Insurance Exchange (also called Health Insurance Marketplace
The scope of this Panel also includes advising on issues pertaining to the education of providers and stakeholders with respect to the Affordable Care Act and certain provisions of the Health Information Technology for Economic and Clinical Health (HITECH) Act enacted as part of the American Recovery and Reinvestment Act of 2009 (ARRA).
On January 21, 2011, the Panel's charter was renewed and the Panel was renamed the Advisory Panel for Outreach and Education. The Panel's charter was most recently renewed on January 19, 2017, and will terminate on January 19, 2019 unless renewed by appropriate action.
Under the current charter, the APOE will advise the Secretary and the Administrator on optimal strategies for the following:
• Developing and implementing education and outreach programs for individuals enrolled in, or eligible for, Medicare, Medicaid, and the CHIP; or coverage available through the Health Insurance Marketplace
• Enhancing the federal government's effectiveness in informing Health Insurance Marketplace
• Expanding outreach to vulnerable and underserved communities, including racial and ethnic minorities, in the context of Health Insurance Marketplace
• Assembling and sharing an information base of “best practices” for helping consumers evaluate health coverage options.
• Building and leveraging existing community infrastructures for information, counseling, and assistance.
• Drawing the program link between outreach and education, promoting consumer understanding of health care coverage choices, and facilitating consumer selection/enrollment, which in turn support the overarching goal of improved access to quality care, including prevention services, envisioned under the Affordable Care Act.
The current members of the Panel are: Kellan Baker, Associate Director, Center for American Progress; Robert Blancato, President, National Association of Nutrition and Aging Services Programs; Deborah Britt, Executive Director of Community & Public Relations, Piedmont Fayette Hospital; Deena Chisolm, Associate Professor of Pediatrics & Public Health, The Ohio State University, Nationwide Children's Hospital; Robert Espinoza, Vice President of Policy, Paraprofessional Healthcare Institute; Louise Scherer Knight, Director, The Sidney Kimmel Comprehensive Cancer Center at Johns Hopkins; Roanne Osborne-Gaskin, M.D., Senior Medical Director, MDWise, Inc.; Cathy Phan, Outreach and Education Coordinator, Asian American Health Coalition DBA HOPE Clinic; Kamilah Pickett, Litigation Support, Independent Contractor; Alvia Siddiqi, Medicaid Managed Care Community Network (MCCN) Medical Director, Advocate Physician Partners, Carla Smith, Executive Vice President, Healthcare Information and Management Systems Society (HIMSS); Tobin Van Ostern, Vice President and Co-Founder, Young Invincibles Advisors; and Paula Villescaz, Senior Consultant, Assembly Health Committee, California State Legislature.
In accordance with section 10(a) of the FACA, this notice announces a meeting of the APOE. The agenda for the September 26, 2018 meeting will include the following:
Individuals or organizations that wish to make a 5-minute oral presentation on an agenda topic should submit a written copy of the oral presentation to the DFO at the address listed in the
The meeting is open to the public, but attendance is limited to the space available. Persons wishing to attend this meeting must register by contacting the DFO at the address listed in the
The REAL ID Act of 2005 (Pub. L. 109-13) establishes minimum standards for the issuance of state-issued driver's licenses and identification (ID) cards. It prohibits federal agencies from accepting an official driver's license or ID card from a state for any official purpose unless the Secretary of the Department of Homeland Security determines that the state meets these standards. Beginning October 2015, photo IDs (such as a valid driver's license) issued by a state or territory not in compliance with the Real ID Act will not be accepted as identification to enter federal buildings. Visitors from these states/territories will need to provide alternative proof of identification (such as a valid passport) to gain entrance into federal buildings. The current list of states from which a federal agency may accept driver's licenses for an official purpose is found at
We recommend that confirmed registrants arrive reasonably early, but no earlier than 45 minutes prior to the start of the meeting, to allow additional time to clear security. Security measures include the following:
• Presentation of a government-issued photographic identification to the Federal Protective Service or Guard Service personnel.
• Inspection, via metal detector or other applicable means, of all persons entering the building. We note that all items brought into HHH Building, whether personal or for the purpose of presentation or to support a presentation, are subject to inspection. We cannot assume responsibility for coordinating the receipt, transfer, transport, storage, set up, safety, or timely arrival of any personal belongings or items used for presentation or to support a presentation.
This document does not impose information collection requirements, that is, reporting, recordkeeping or third-party disclosure requirements. Consequently, there is no need for review by the Office of Management and Budget under the authority of the Paperwork Reduction Act of 1995 (44 U.S.C. Chapter 35).
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Office of the Secretary, HHS.
Notice.
Findings of research misconduct have been made on the part of Li Wang, Ph.D., Professor of Physiology and Neurobiology, University of Connecticut (UConn) (Respondent). Dr. Wang engaged in research misconduct in research included in National Institute of Diabetes and Digestive and Kidney Diseases (NIDDK), National Institutes of Health (NIH), grant applications 1 R01 DK118645-01A1, 1 R01 DK116203-01, 1 R01 DK114804-01, and 2 R01 DK080440-09A1 and National Institute of General Medical Sciences (NIGMS), NIH, grant applications 1 R01 GM125140-01 and 1 R01 GM126685-01. The administrative actions, including supervision for a period of one (1) year, were implemented beginning on August 14, 2018, and are detailed below.
Wanda K. Jones, Dr.P.H., Interim Director, Office of Research Integrity, 1101 Wootton Parkway, Suite 750, Rockville, MD 20852, (240) 453-8200.
Notice is hereby given that the Office of Research Integrity (ORI) has taken final action in the following case:
In addition to making an admission, Respondent cooperated fully with UConn and ORI, has expressed remorse for her actions, and took full responsibility for her reckless behavior.
Specifically, ORI finds that:
• Respondent mislabeled figure images in four grant applications, as follows:
• in Figure 10 in 1 R01 DK118645-01A1, Respondent used Western blot
• in Figure 13C in 1 R01 DK114804-01 and Figure 14C in 2 R01 DK080440-09A1, Respondent presented Western blot data showing decreased HMGB2 expression over time in primary HSCs when she knew these preliminary data were not sufficiently robust Dr. Wang entered into a Voluntary Settlement Agreement and voluntarily agreed for a period of one (1) year, beginning on August 14, 2018:
(1) To have her research supervised; Respondent agrees that prior to the submission of an application for U.S. Public Health Service (PHS) support for a research project on which the Respondent's participation is proposed and prior to Respondent's participation in any capacity on PHS-supported research, Respondent shall ensure that a plan for supervision of Respondent's duties is submitted to ORI for approval; the supervision plan must be designed to ensure the scientific integrity of Respondent's research contribution; Respondent agrees that she shall not participate in any PHS-supported research until such a supervision plan is submitted to and approved by ORI; Respondent agrees to maintain responsibility for compliance with the agreed upon supervision plan;
(2) that any institution employing her shall submit, in conjunction with each application for PHS funds, or report, manuscript, or abstract involving PHS-supported research in which Respondent is involved, a certification to ORI that the data provided by Respondent are based on actual experiments or are otherwise legitimately derived and that the data, procedures, and methodology are accurately reported in the application, report, manuscript or abstract; and
(3) to exclude herself voluntarily from serving in any advisory capacity to PHS including, but not limited to, service on any PHS advisory committee, board, and/or peer review committee, or as a consultant.
Office of the Secretary, HHS.
Notice.
In compliance with the requirement of the Paperwork Reduction Act of 1995, the Office of the Secretary (OS), Department of Health and Human Services, is publishing the following summary of a proposed collection for public comment.
Comments on the ICR must be received on or before October 1, 2018.
Submit your comments to
Sherrette Funn,
Interested persons are invited to send comments regarding this burden estimate or any other aspect of this collection of information, including any of the following subjects: (1) The necessity and utility of the proposed information collection for the proper performance of the agency's functions; (2) the accuracy of the estimated burden; (3) ways to enhance the quality, utility, and clarity of the information to be collected; and (4) the use of automated collection techniques or other forms of information technology to minimize the information collection burden.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended, 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.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended, 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, 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, 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
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended, 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, 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.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended, 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, 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.
U.S. Customs and Border Protection, Department of Homeland Security.
Notice of accreditation and approval of Inspectorate America Corporation (Pasadena, TX), as a commercial gauger and laboratory.
Notice is hereby given, pursuant to CBP regulations, that Inspectorate America Corporation (Pasadena, TX), has been approved to gauge petroleum and certain petroleum products and accredited to test petroleum and certain petroleum products for customs purposes for the next three years as of February 7, 2018.
Inspectorate America Corporation (Pasadena, TX) was accredited and approved, as a commercial gauger and laboratory as of February 7, 2018. The next triennial inspection date will be scheduled for February 2021.
Dr. Justin Shey, Laboratories and Scientific Services Directorate, U.S. Customs and Border Protection, 1300 Pennsylvania Avenue NW, Suite 1500N, Washington, DC 20229, tel. 202-344-1060.
Notice is hereby given pursuant to 19 CFR 151.12 and 19 CFR 151.13, that Inspectorate America Corporation, 141 N. Pasadena Blvd., Pasadena, TX 77506 has been approved to gauge petroleum and certain petroleum products and accredited to test petroleum and certain petroleum products for customs purposes, in accordance with the provisions of 19 CFR 151.12 and 19 CFR 151.13. Inspectorate America Corporation is approved for the following gauging procedures for petroleum and certain petroleum products from the American Petroleum Institute (API):
Inspectorate America Corporation is accredited for the following laboratory analysis procedures and methods for petroleum and certain petroleum products set forth by the U.S. Customs and Border Protection Laboratory Methods (CBPL) and American Society for Testing and Materials (ASTM):
Anyone wishing to employ this entity to conduct laboratory analyses and gauger services should request and receive written assurances from the entity that it is accredited or approved by the U.S. Customs and Border Protection to conduct the specific test or gauger service requested. Alternatively, inquiries regarding the specific test or gauger service this entity is accredited or approved to perform may be directed to the U.S. Customs and Border Protection by calling (202) 344-1060. The inquiry may also be sent to
U.S. Immigration and Customs Enforcement, Department of Homeland Security.
60-Day notice.
The Department of Homeland Security, U.S. Immigration and Customs Enforcement (USICE), will be submitting the following information collection request for review and clearance in accordance with the Paperwork Reduction Act of 1995. The information collection is published in the
Comments are encouraged and will be accepted for sixty days until October 30, 2018.
Written comments and suggestions regarding items contained in this notice and especially regarding the estimated public burden and associated response time should be directed to the Office of the Chief Information Office, PRA Clearance, U.S. Immigration and Customs Enforcement by one of the following methods:
(1)
(2)
Written comments and suggestions from the public and affected agencies concerning the proposed collection of information should address one or more of the following four points:
(1) Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(2) Evaluate the accuracy of the agencies estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
(3) Enhance the quality, utility, and clarity of the information to be collected; and
(4) Minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
(1)
(2)
(3)
(4)
(5)
(6)
U.S. Citizenship and Immigration Services, Department of Homeland Security.
60-Day notice.
The Department of Homeland Security (DHS), U.S. Citizenship and Immigration (USCIS) invites the general public and other Federal agencies to comment upon this proposed extension of a currently approved collection of information. In accordance with the Paperwork Reduction Act (PRA) of 1995, the information collection notice is published in the
Comments are encouraged and will be accepted for 60 days until October 30, 2018.
All submissions received must include the OMB Control Number 1615-0037 in the body of the letter, the agency name and Docket ID USCIS-2007-0030. To avoid duplicate submissions, please use only
(1)
USCIS, Office of Policy and Strategy, Regulatory Coordination Division, Samantha Deshommes, Chief, 20 Massachusetts Avenue NW, Washington, DC 20529-2140, telephone number 202-272-8377 (This is not a toll-free number. Comments are not accepted via telephone message). Please note contact information provided here is solely for questions regarding this notice. It is not for individual case status inquiries. Applicants seeking information about the status of their individual cases can check Case Status Online, available at the USCIS website at
You may access the information collection instrument with instructions, or additional information by visiting the Federal eRulemaking Portal site at:
Written comments and suggestions from the public and affected agencies should address one or more of the following four points:
(1) Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(2) Evaluate the accuracy of the agency's estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
(3) Enhance the quality, utility, and clarity of the information to be collected; and
(4) Minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
(1)
(2)
(3)
(4)
(5)
(6)
(7)
U.S. Citizenship and Immigration Services, Department of Homeland Security.
30-Day notice.
The Department of Homeland Security (DHS), U.S. Citizenship and Immigration Services (USCIS) will be submitting the following information collection request to the Office of Management and Budget (OMB) for review and clearance in accordance with the Paperwork Reduction Act of
The purpose of this notice is to allow an additional 30 days for public comments. Comments are encouraged and will be accepted until October 1, 2018.
Written comments and/or suggestions regarding the item(s) contained in this notice, especially regarding the estimated public burden and associated response time, must be directed to the OMB USCIS Desk Officer via email at
You may wish to consider limiting the amount of personal information that you provide in any voluntary submission you make. For additional information please read the Privacy Act notice that is available via the link in the footer of
USCIS, Office of Policy and Strategy, Regulatory Coordination Division, Samantha Deshommes, Chief, 20 Massachusetts Avenue NW, Washington, DC 20529-2140, Telephone number (202) 272-8377 (This is not a toll-free number; comments are not accepted via telephone message.). Please note contact information provided here is solely for questions regarding this notice. It is not for individual case status inquiries. Applicants seeking information about the status of their individual cases can check Case Status Online, available at the USCIS website at
The information collection notice was previously published in the
You may access the information collection instrument with instructions, or additional information by visiting the Federal eRulemaking Portal site at:
(1) Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(2) Evaluate the accuracy of the agency's estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
(3) Enhance the quality, utility, and clarity of the information to be collected; and
(4) Minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
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Office of the Assistant Secretary for Policy Development and Research, HUD.
Notice of Fiscal Year (FY) 2019 Fair Market Rents (FMRs) and response to public comments on the use of FMR surveys in the calculation of renewal funding inflation factors.
Section 8(c)(1) of the United States Housing Act of 1937 (USHA), as amended by the Housing Opportunity Through Modernization Act of 2016 (HOTMA), requires the Secretary to publish FMRs not less than annually, adjusted to be effective on October 1 of each year. This notice describes the methods used to calculate the FY 2019 FMRs and enumerates the procedures for Public Housing Agencies (PHAs) and other interested parties to request reevaluations of their FMRs, as required by HOTMA. To help inform PHAs' decisions concerning reevaluation requests, this notice briefly addresses HUD's May 30, 2018 notice regarding the use of FMR surveys in the calculation of Renewal Funding Inflation Factors.
HUD invites interested persons to submit comments regarding the FMRs and to request reevaluation of the FY 2019 FMRs to the Regulations Division, Office of General Counsel, Department of Housing and Urban Development, 451 Seventh Street SW, Room 10276, Washington, DC 20410-0001. Communications must refer to the above docket number and title and should contain the information specified in the “Request for Comments/Request for Reevaluation” section. There are two methods for submitting public comments.
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To receive consideration as public comments or reevaluation requests, comments or requests must be submitted through one of the two methods specified above. Again, all submissions must refer to the docket number and title of the notice.
For technical information on the methodology used to develop FMRs or a listing of all FMRs, please call the HUD USER information line at 800-245-2691 or access the information on the HUD USER website at
Questions related to use of FMRs or voucher payment standards should be directed to the respective local HUD program staff. Questions on how to conduct FMR surveys may be addressed to Marie L. Lihn or Peter B. Kahn of the Economic and Market Analysis Division, Office of Economic Affairs, Office of Policy Development and Research at HUD headquarters, 451 7th Street SW, Room 8208, Washington, DC 20410; telephone number 202-402-2409 (this is not a toll-free number), or via email at
Section 8 of the USHA (42 U.S.C. 1437f) authorizes housing assistance to aid lower-income families in renting safe and decent housing. Housing assistance payments are limited by FMRs established by HUD for different geographic areas. In the Housing Choice Voucher (HCV) program, the FMR is the basis for determining the “payment standard amount” used to calculate the maximum monthly subsidy for an assisted family. See 24 CFR 982.503. HUD also uses the FMRs to determine initial renewal rents for some expiring project-based Section 8 contracts, initial rents for housing assistance payment contracts in the Moderate Rehabilitation Single Room Occupancy program, rent ceilings for rental units in both the HOME Investment Partnerships program and the Emergency Solution Grants program, calculation of maximum award amounts for Continuum of Care recipients and the maximum amount of rent a recipient may pay for property leased with Continuum of Care funds, and calculation of flat rents in Public Housing units. 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 and is typically set at the 40th percentile of the distribution of gross rents. HUD's FMR calculations represent HUD's best effort to estimate the 40th percentile gross rent paid by recent movers into standard quality units in each FMR area. In addition, all rents subsidized under the HCV program must meet reasonable rent standards.
As of October 2, 2000, HUD required FMRs to be set at the 50th percentile for areas where HUD determined higher FMRs were needed to help families assisted under certain HUD programs find and lease decent and affordable housing (65 FR 58870). On November 16, 2016, HUD published a Final Rule entitled “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” (Small Area FMR final rule) (81 FR 80567), with an effective date of January 17, 2017. The Small Area FMR final rule eliminates the 50th percentile FMR provisions in the FMR regulations (24 CFR 888.113)
The following areas completed their 3 years of 50th percentile eligibility in FY 2018 and will revert to 40th percentile FMR status in FY 2019:
The following is a list of FMR areas that retain 50th percentile FMRs for FY 2019, along with the year that they will revert to 40th percentile status:
Section 8(c)(1) of the USHA, as amended by the Housing Opportunity Through Modernization Act of 2016 (HOTMA) (Pub. L. 114-201, approved July 29, 2016), requires the Secretary of HUD to publish FMRs not less than annually. Section 8(c)(1)(A) states that each FMR “shall be adjusted to be effective on October 1 of each year to reflect changes, based on the most recent available data trended so the rentals will be current for the year to which they apply . . .” Section 8(c)(1)(B) requires that HUD publish, not less than annually, new FMRs on the World Wide Web or in any other manner specified by the Secretary, and that HUD must also notify the public of when it publishes FMRs by
This section provides a brief overview of how HUD computes the FY 2019 FMRs. HUD is making no changes to the estimation methodology for FMRs as used by HUD for the FY 2018 FMRs. The only difference is the use of more recent data. For complete information on how HUD determines FMR areas, and on how HUD derives each area's FMRs, see the online documentation at
In conjunction with the use of 2016 American Community Survey (ACS) data, HUD has implemented the following geography changes: Effective May 1, 2016, Garfield County, Oklahoma became the metropolitan area of Enid, OK metropolitan statistical area (MSA). In addition, HUD changed from two separate county-based HUD Metro FMR Areas (HMFA) (Kalawao County, HI HMFA and Maui County, HI HMFA) to a two county MSA, the Kahului-Wailuku-Lahaina, HI MSA due to extremely limited data available for Kalawao County, HI.
For FY 2019 FMRs, HUD uses the U.S. Census Bureau's 5-year ACS data collected between 2012 and 2016 (released in December 2017) as the base rents for the FMR calculations. In order to improve the statistical reliability of the ACS data used in the FMR calculations, HUD pairs a “margin of error” test
For areas in which the 5-year ACS data for two-bedroom, standard quality gross rents do not pass the statistical reliability tests (
Since FY 2012, HUD has updated base rents each year based on new 5-year data, for which HUD used 2005-2009 ACS data. HUD is also updating base rents for Puerto Rico FMRs using data collected through the Puerto Rico Community Surveys (PRCS) between 2012 and 2016. HUD first updated the Puerto Rico base rents in FY 2014 based on 2007-2011 PRCS data collected through the ACS program.
HUD historically based FMRs on gross rents for recent movers (those who have moved into their current residence in the last 24 months) measured directly from decennial census long form survey responses. However, due to the way the 5-year ACS data are constructed, HUD developed a new method for calculating recent-mover FMRs in FY 2012, which HUD continues to use in FY 2019: HUD assigns all areas a base rent, which is the two-bedroom standard quality 5-year gross rent estimate from the ACS; then, because HUD's regulations mandate that FMRs must be published as recent mover gross rents, HUD applies a recent mover factor to the base rents assigned from the 5-year ACS data.
Following the assignment of the standard quality two-bedroom rent described above, HUD applies a recent mover factor to these rents. HUD calculates the recent mover factor as the change between the 5-year 2012-2016 standard quality two-bedroom gross rent and the 1-year 2016 recent mover gross rent for the recent mover factor area. HUD does not allow recent mover factors to lower the standard quality base rent; therefore, if the 5-year standard quality rent is larger than the comparable 1-year recent mover rent, the recent mover factor is set to 1.
The calculation of the recent mover factor for FY 2019 continues with the modifications first applied to the FY 2018 FMRs. Similar to the statistical reliability requirements for base rents, for a recent mover gross rent estimate to be considered statistically reliable, the estimate must have a margin of error ratio that is less than 50 percent, and the estimate must be based on 100 or more observations.
When an FMR area does not have statistically reliable two-bedroom recent mover data, the “all-bedroom”
However, where statistically reliable “all-bedroom” data is not available, HUD will continue to base FMR areas' recent mover factors on larger geographic areas, following the same procedures used historically: HUD tests data from differently sized geographic areas from small to large, and bases the recent mover factor on the first statistically reliable recent mover rent estimate in the geographic hierarchy listed below.
• For metropolitan areas that are subareas of larger metropolitan areas, the order is the FMR area, metropolitan area, aggregated metropolitan parts of the state, and state.
• For metropolitan areas that are not divided, the order is the FMR area, aggregated metropolitan parts of the state, and the state.
• In non-metropolitan areas, the order is the FMR area, aggregated non-metropolitan parts of the state, and the state.
The process for calculating each area's recent mover factor is detailed in the FY 2019 FMR documentation system available at:
HUD calculated base rents for the insular areas using the 2010 decennial census of American Samoa, Guam, the Northern Mariana Islands, and the Virgin Islands beginning with the FY 2016 FMRs.
HUD does not use ACS data to establish the base rent or recent mover factor for 10 areas where the FY 2018 FMR was adjusted based on the following survey data:
• Survey data from 2016 is used to adjust the FMR for Portland, ME.
• Survey data from 2017 is used to adjust the FMRs for Santa Rosa, CA; Seattle-Bellevue, WA HMFA; Hood River County, OR; Wasco County, OR; Hawaii County, HI; Jonesboro, AR HMFA; Urban Honolulu, HI MSA; and Santa Maria-Santa Barbara, CA MSA.
• Survey data from 2018 is used to adjust the FMR for Santa Cruz-Watsonville, CA MSA.
For larger metropolitan areas that have valid ACS one-year recent mover data, survey data may not be any older than the midpoint of the calendar year for the ACS one-year data. Since the ACS one-year data used for the FY 2019 FMRs is from 2016, larger areas may not use survey data collected before June 30, 2016, for the FY 2019 FMRs. Smaller areas without 1-year ACS data, may continue to use local survey data until the mid-point of the 5-year ACS data is more recent than the local survey.
HUD updates the ACS-based “as of” 2016 rent through the end of 2017 using the annual change in gross rents measured through the Consumer Price Index (CPI) from 2016 to 2017 (CPI update factor). As in previous years, HUD uses local CPI data coupled with Consumer Expenditure Survey data for FMR areas with at least 75 percent of their population within Class A metropolitan areas covered by local CPI data. In FMR areas that do not meet this criterion, including Class B and C size metropolitan areas and non-metropolitan areas, HUD uses CPI data aggregated at the Census region level. Additionally, HUD is using CPI data collected locally in Puerto Rico as the basis for CPI adjustments from 2016 to 2017 for all Puerto Rico FMR areas.
Following the application of the appropriate CPI update factor, HUD trends the gross rent estimate from 2017 to FY 2019 using a national forecast of expected growth in gross rents. This forecast produces “as of” FY 2019 FMRs.
HUD updates the bedroom ratios used in the calculation of FMRs annually. The bedroom ratios which HUD used in the calculation of FY 2019 FMRs have been updated using average data from three 5-year ACS data series (2010-2014, 2011-2015, and 2012-2016). The bedroom ratio methodology used in this update is unchanged from previous calculations using 2000 Census data. HUD only uses estimates with a margin of error ratio of less than 50 percent. If an area does not have reliable estimates in at least two of the previous three ACS releases, bedroom ratios for the area's larger parent geography are used.
HUD uses two-bedroom units for its primary calculation of FMR estimates. This is generally the most common size of rental unit and, therefore, the most reliable to survey and analyze. After estimating two-bedroom FMRs, HUD calculates bedroom ratios for each FMR area which relate the prices of smaller and larger units to the cost of two-bedroom units. To prevent illogical results in particular FMR areas, HUD establishes bedroom interval ranges which set upper and lower limits for bedroom ratios nationwide, based on an analysis of the range of such intervals for all areas with large enough samples to permit accurate bedroom ratio determinations.
In the calculation of FY 2019 FMR estimates, HUD set the bedroom interval ranges as follows: Efficiency FMRs are constrained to fall between 0.64 and 0.85 of the two-bedroom FMR; one-bedroom FMRs must be between 0.76 and 0.87 of the two-bedroom FMR; three-bedroom FMRs (prior to the adjustments described below) must be between 1.15 and 1.33 of the two-bedroom FMR; and four-bedroom FMRs (again, prior to adjustment) must be between 1.26 and 1.63 of the two-bedroom FMR. Given that these interval ranges partially overlap across unit bedroom counts, HUD further adjusts bedroom ratios for a given FMR area, if necessary, to ensure that higher bedroom-count units have higher rents than lower bedroom-count units within that area. The bedroom ratios for Puerto Rico follow these constraints.
HUD also further adjusts the rents for three-bedroom and larger units to reflect HUD's policy to set higher rents for these units.
HUD derives FMRs for units with more than four bedrooms by adding 15 percent to the four-bedroom FMR for each extra bedroom. For example, the FMR for a five-bedroom unit is 1.15 times the four-bedroom FMR, and the FMR for a six-bedroom unit is 1.30 times the four-bedroom FMR. Similarly, HUD derives FMRs for single-room occupancy units by subtracting 25 percent from the zero-bedroom FMR (
Within the Small Area FMR final rule published on November 16, 2016, HUD amended 24 CFR 888.113 to include a limit on the amount that FMRs may annually decrease. The current year's FMRs resulting from the application of the bedroom ratios, as discussed in section (E) above, may be no less than 90 percent of the prior year's FMRs for units with the same number of bedrooms. Accordingly, if the current year's FMRs are less than 90 percent of the prior year's FMRs as calculated by the above methodology, HUD sets the current year's FMRs equal to 90 percent of the prior year's FMRs. For areas where use of Small Area FMRs in the administration of their voucher programs is required, the FY 2019 Small Area FMRs may be no less than 90 percent of the FY 2018 Small Area FMRs. For all other metropolitan areas, for which Small Area FMRs are calculated so that they may be used for other allowable purposes if desired (
All FMRs are subject to a state or national minimum. HUD calculates a population-weighted median two-bedroom 40th percentile rent across all non-metropolitan portions of each state, which, for the purposes of FMRs, is the state minimum rent. State-minimum rents for each FMR area are available in the FY 2019 FMR Documentation System, available at
As in prior years, Small Area FMRs are subject to a maximum limit. HUD limits each two-bedroom Small Area FMR to be no more than 150 percent of the two-bedroom FMR for the metropolitan area where the ZIP code is located.
HOTMA changed the manner in which vouchers are used to subsidize manufactured home units. Please see HUD's Notice from January 18, 2017 (82 FR 5458) for more detailed information concerning the use of vouchers for manufactured home units. Due to the nature of these changes, HUD will no longer be publishing exception rents for Manufactured Home Space pad rents.
PHAs operating the Housing Choice Voucher (HCV) program in the 24 metropolitan areas identified in the November 16, 2016
In the FY 2018 FMR
For ZCTAs without usable gross rent data by bedroom size, HUD will continue to calculate Small Area FMRs using the rent ratio method similar to that which HUD has used in past Small Area FMR calculations. To calculate Small Area FMRs using a rent ratio, HUD divides the median gross rent across all bedrooms for the small area (a ZIP code) by the similar median gross rent for the metropolitan area of the ZIP code. In small areas where the median gross rent is not statistically reliable, HUD substitutes the median gross rent for the county containing the ZIP code in the numerator of the rent ratio calculation. HUD multiplies this rent ratio by the current two-bedroom rent for the metropolitan area containing the small area to generate the current year two-bedroom rent for the small area.
HUD continues to use a rolling average of ACS data in calculating the Small Area FMR rent ratios. HUD believes coupling the most current data with previous year's data minimizes excessive year-to-year variability in Small Area FMR rent ratios due to sampling variance. Therefore, for FY 2019 Small Area FMRs, HUD has updated the rent ratios to use an average of the rent ratios calculated from the 2010-2014, 2011-2015, and 2012-2016 5-year ACS estimates.
Although HUD has not changed the FMR estimation method for FY 2019, HUD will continue to accept public comments on the methods HUD uses to calculate FY 2019 FMRs, including Small Area FMRs, and the FMR levels for specific areas. Due to its current funding levels, HUD no longer has sufficient resources to conduct local surveys of rents to address comments filed regarding the FMR levels for specific areas. PHAs may continue to fund such surveys independently, as specified below, using administrative fees if they so choose. HUD continually strives to calculate FMRs that meet the statutory requirement of using “the most recent available data” while also serving as an effective program parameter.
PHAs or other interested parties interested in requesting HUD reevaluation of their area's FY 2019 FMRs, as provided for under section 8(c)(1)(B) of USHA, must follow the following procedures:
1. By the end of the comment period, such reevaluation requests must be submitted publicly through
2. In order for a reevaluation to occur, the requestor(s) must supply HUD with data more recent than the 2016 American Community Survey data used in the calculation of the FY 2019 FMRs. HUD requires data on gross rents paid in the FMR area for standard quality rental housing units. The data delivered must be sufficient for HUD to calculate a 40th and 50th percentile two-bedroom rent. Should this type of data not be available, requestors may gather this information using the survey guidance available at
3. On or about October 2, HUD will post a list, at
4. Data for reevaluations must be supplied to HUD no later than Friday, January 11, 2019. On Monday January 14, 2018, HUD will post at
5. HUD will use the data delivered by January 11, 2019, to reevaluate the FMRs and following the reevaluation, will post revised FMRs with an accompanying
6. Any data supporting a change in FMRs supplied after January 11, 2019, will be incorporated into FY 2020 FMRs.
7. PHAs operating in areas where the calculated FMR is lower than the published FMR (
For small metropolitan areas without one-year ACS data and non-metropolitan counties, HUD has developed a method using mail surveys that is discussed on the FMR web page:
While HUD has not developed a specific method for mail surveys in areas with 1-year ACS data or in areas not covered by ACS data, HUD will apply the standard established for Random-Digit Dialing (RDD) telephone rent surveys. HUD will evaluate these survey results to determine whether to establish a new FMR statistically different from the current FMR, which means that the survey confidence interval must not include the FMR. The survey should collect results based on 200 one-bedroom and two-bedroom eligible recent mover units to provide a small enough confidence interval for significant results in large market mail surveys. Areas with statistically reliable 1-year ACS data are not considered to be good candidates for local surveys due to the size and completeness of the ACS process.
Other survey methods are acceptable in providing data to support reevaluation requests if the survey method can provide statistically reliable, unbiased estimates of the gross rent of the entire FMR area. In general, recommendations for FMR changes and supporting data must reflect the rent levels that exist within the entire FMR area and should be statistically reliable.
PHAs in non-metropolitan areas may, in certain circumstances, conduct surveys of groups of counties. HUD must approve all county-grouped surveys in advance. PHAs are cautioned
Survey samples should preferably be randomly drawn from a complete list of rental units for the FMR area. If this is not feasible, the selected sample must be drawn to be statistically representative of the entire rental housing stock of the FMR area. Surveys must include units at all rent levels and be representative by structure type (including single-family, duplex, and other small rental properties), age of housing unit, and geographic location. The current 5-year ACS data should be used as a means of verifying if a sample is representative of the FMR area's rental housing stock.
A PHA or contractor that cannot obtain the recommended number of sample responses after reasonable efforts should consult with HUD before abandoning its survey; in such situations, HUD may find it appropriate to relax normal sample size requirements.
HUD has developed guidance on how to provide data-supported comments on Small Area FMRs using HUD's special tabulations of the distribution of gross rents by unit bedroom count for ZIP Code Tabulation Areas. This guidance is available at
As stated earlier in this notice, HUD is required to use the most recent data available when calculating FMRs. Therefore, in order to reevaluate an area's FMR, HUD requires more current rental market data than the 2016 ACS. HUD encourages a PHA or other interested party that believes the FMR in their area is incorrect to file a comment even if they do not have the resources to provide market-wide rental data. In these instances, HUD will use the comments, should survey funding be restored, when determining the areas HUD will select for HUD-funded local area rent surveys.
HUD received 10 comments addressing the use of FMR surveys in the calculation of Renewal Funding Inflation Factors (RFIFs). Most of the comments received directed HUD to continue using FMR surveys in the calculation of RFIFs. Consequently, HUD does not have current plans to discontinue use of FMR surveys in the rent change component of RFIF calculations. HUD is still determining the exact methods to use when incorporating surveys in RFIF calculations. Public comments will be discussed in greater detail, and HUD's responses will be provided, in the 2019 Renewal Funding Inflation Factor notice. HUD provides the above information in this notice for the awareness of PHAs that are considering undertaking a survey to reevaluate their FY 2019 FMRs.
This Notice involves the establishment of FMR schedules, which do not constitute a development decision affecting the physical condition of specific project areas or building sites. Accordingly, under 24 CFR 50.19(c)(6), this Notice is categorically excluded from environmental review under the National Environmental Policy Act of 1969 (42 U.S.C. 4321).
Accordingly, the Fair Market Rent Schedules, which will not be codified in 24 CFR part 888, are available at
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Specific counties and New England towns and cities within each state in MSAs and HMFAs were not changed by the February 28, 2013 OMB metropolitan area definitions. These areas are listed in Schedule B, available online at
Schedule B, available at
a. FMR areas in online Schedule B are listed alphabetically by metropolitan FMR area and by non-metropolitan county within each state and are available at
b. Constituent counties (and New England towns and cities) included in each metropolitan FMR area are listed immediately following the listings of the FMR dollar amounts. All constituent parts of a metropolitan FMR area that are in more than one state can be identified by consulting the listings for each applicable state.
c. Two non-metropolitan counties are listed alphabetically on each line of the non-metropolitan county listings.
d. The New England towns and cities included in a non-metropolitan county are listed immediately following the county name.
Office of the Chief Information Officer, HUD.
Notice.
HUD submitted the proposed information collection requirement described below to the Office of Management and Budget (OMB) for review, in accordance with the Paperwork Reduction Act. The purpose of this notice is to allow for 30 days of public comment.
Interested persons are invited to submit comments regarding this proposal. Comments should refer to the proposal by name and/or OMB Control Number and should be sent to: HUD Desk Officer, Office of Management and Budget, New Executive Office Building, Washington, DC 20503; fax: 202-395-5806, Email:
Colette Pollard, Reports Management Officer, QMAC, Department of Housing and Urban Development, 451 7th Street SW, Washington, DC 20410; email
Copies of available documents submitted to OMB may be obtained from Ms. Pollard.
This notice informs the public that HUD is seeking approval from OMB for the information collection described in Section A.
The
This notice is soliciting comments from members of the public and affected parties concerning the collection of information described in Section A on the following:
(1) Whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(2) The accuracy of the agency'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 those who are to respond: including through the use of appropriate automated collection techniques or other forms of information technology,
HUD encourages interested parties to submit comment in response to these questions.
Section 3507 of the Paperwork Reduction Act of 1995, 44 U.S.C. Chapter 35.
Office of the Chief Information Officer, HUD.
Notice.
HUD submitted the proposed information collection requirement described below to the Office of Management and Budget (OMB) for review, in accordance with the Paperwork Reduction Act. The purpose of this notice is to allow for 30 days of public comment.
Interested persons are invited to submit comments regarding this proposal. Comments should refer to the proposal by name and/or OMB Control Number and should be sent to: HUD Desk Officer, Office of Management and Budget, New Executive Office Building, Washington, DC 20503; fax: 202-395-5806, Email:
Inez C. Downs, Reports Management Officer, QMAC, Department of Housing and Urban Development, 451 7th Street SW, Washington, DC 20410; email
Copies of available documents submitted to OMB may be obtained from Ms. Downs.
This notice informs the public that HUD is seeking approval from OMB for the information collection described in Section A.
The
This notice is soliciting comments from members of the public and affected parties concerning the collection of information described in Section A on the following:
(1) Whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
(2) The accuracy of the agency'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 those who are to respond: Including through the use of appropriate automated collection techniques or other forms of information technology,
HUD encourages interested parties to submit comment in response to these questions.
Section 3507 of the Paperwork Reduction Act of 1995, 44 U.S.C. Chapter 35.
Fish and Wildlife Service, Interior.
Notice of availability; request for comments.
In accordance with the Endangered Species Act, as amended (ESA), and the National Environmental Policy Act (NEPA), we, the U.S. Fish and Wildlife Service (Service), announce the availability of a draft habitat conservation plan (HCP) in support of an application from MidAmerican Energy Company (applicant) for an incidental take permit (ITP) for the federally endangered Indiana bat, federally threatened northern long-eared bat, and federally protected bald eagle; also included in the permit would be the little brown bat and tricolored bat. The take is expected to result from operation of wind turbines in 22 counties in Iowa. Also available for review is the Service's draft environmental impact statement (DEIS), which was prepared in response to the application. We are seeking public comments on the draft HCP and DEIS.
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We will post all comments on
Amber Schorg or Kraig McPeek, by phone at 309-757-5800.
The Service has received an incidental take permit (ITP) application from the MidAmerican Energy Company in accordance with the requirements of the Endangered Species Act, as amended (ESA; 16 U.S.C. 1531
The Service has prepared a draft environmental impact statement (DEIS) in response to the ITP application in accordance with requirements of the National Environmental Policy Act (NEPA; 42 U.S.C. 4321
Section 9 of the ESA and its implementing regulations prohibit the “take” of animal species listed as endangered or threatened.
Section 10(a)(1)(B) of the ESA contains provisions for issuing incidental take permits to non-Federal entities for the incidental take of endangered and threatened species, provided the following criteria are met: (a) The taking will be incidental; (b) the applicant will minimize and mitigate, to the maximum extent practicable, the impact of such taking; (c) the applicant will develop an HCP and ensure that adequate funding for the plan will be provided; (d) the taking will not appreciably reduce the likelihood of the survival and recovery of the species in the wild; and (e) the applicant will carry out any other measures that the Secretary of the Interior may require as being necessary or appropriate for the purposes of the HCP. An applicant may choose to cover nonlisted species in the HCP, and these species will be treated as ESA-listed species.
We propose to issue a 30-year permit for incidental take of the Indiana bat, northern long-eared bat, bald eagle, little brown bat, and tricolored bat if the MidAmerican HCP meets all the section 10(a)(1)(B) permit issuance criteria. The permit would authorize the take of these species incidental to the applicant's operation of wind projects.
MidAmerican Energy currently operates 22 Projects in Iowa, consisting of 2,021 turbines that vary by type and project. Detailed descriptions of the projects are found in section 2.0 of the HCP. All projects and turbines are within the range of the northern long-eared bat, little brown bat, tricolored bat, and eagle. Four projects have turbines within Indiana bat range (375 turbines). MidAmerican has developed a conservation program to avoid, minimize, and mitigate for impacts to covered species. Bald eagle-specific avoidance and minimization measures will include carrion removal in the vicinity of projects and livestock operator outreach. Reductions in scavenging opportunities are expected to reduce eagle use near wind projects. Bat-specific minimization measures were informed by extensive species presence-absence surveys, migration telemetry studies, and mortality monitoring. Minimization measures will include blade feathering below manufacturer's cut-in speed at all projects from March 15 through November 15 from sunset to sunrise. Additionally, 4 projects (265 turbines) that are expected to have the highest risk to covered bat species and all bats will be feathered below 5.0 meters per second (m/s) July 15 through September 30 from sunset to sunrise when temperatures are below 10 degrees Celsius (50 degrees Fahrenheit). Blade feathering consists of turning turbine blades parallel to the prevailing wind direction to reduce rotation of the turbine rotors, which in turn reduces the likelihood of bat-turbine collisions. MidAmerican will conduct an annual monitoring program at each project throughout the life of the permit to confirm take permit compliance.
MidAmerican has committed to fully offsetting the impacts of the taking for all covered bat species through habitat restoration, preservation, and enhancement, as well as restoration and preservation of at-risk occupied artificial roost structures. Measures to offset the impacts to taking of bald eagles will include funding local or regional eagle rehabilitation, a toxic substance education and abatement program, and protection of key eagle nesting or foraging habitat.
In compliance with NEPA (42 U.S.C. 4321
Seven alternatives are analyzed in the DEIS.
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• The applicant's HCP alternative.
• Participation in the Midwest Wind MSHCP alternative.
The environmental consequences of each alternative were analyzed to determine if significant environmental impacts would occur.
The EPA is charged with reviewing all Federal agencies' EISs and commenting on the adequacy and acceptability of the environmental impacts of proposed actions in EISs. Therefore, EPA is publishing a notice in the
EPA serves as the repository (EIS database) for EISs prepared by Federal agencies. All EISs must be filed with EPA, which publishes a notice of availability on Fridays in the
We will post on
We provide this notice under section 10(c) of the ESA (16 U.S.C. 1531
Bureau of Land Management, Interior.
Notice of official filing.
The plats of survey of the following described lands are scheduled to be officially filed in the Bureau of Land Management (BLM), Colorado State Office, Lakewood, Colorado, 30 calendar days from the date of this publication. The surveys, which were executed at the request of the U.S. Forest Service and the BLM, are necessary for the management of these lands.
Unless there are protests of this action, the plats described in this notice will be filed on October 1, 2018.
You may submit written protests to the BLM Colorado State Office, Cadastral Survey, 2850 Youngfield Street, Lakewood, CO 80215-7093.
Randy Bloom, Chief Cadastral Surveyor for Colorado, (303) 239-3856;
The plat and field notes of the dependent resurvey in Township 14 South, Range 99 West, Sixth Principal Meridian, Colorado, were accepted on July 5, 2018.
The plat, in 4 sheets, incorporating the field notes of the dependent resurvey in Township 2 South, Range 73 West, Sixth Principal Meridian, Colorado, was accepted on July 9, 2018.
The plat, in 2 sheets, incorporating the field notes of the dependent resurvey and subdivision of section 23 in Township 41 North, Range 2 East, New Mexico Principal Meridian, Colorado, was accepted on July 23, 2018.
The plat, in 2 sheets, incorporating the field notes of the dependent resurvey and subdivision of section 27 in Township 4 South, Range 72 West, Sixth Principal Meridian, Colorado, was accepted on August 9, 2018.
A person or party who wishes to protest any of the above surveys must file a written notice of protest within 30 calendar days from the date of this publication at the address listed in the
43 U.S.C. Chap. 3.
Bureau of Land Management, Interior.
Public Land Order.
This order withdraws 694,838.84 acres of public land in Churchill, Lyon, Mineral, Nye, and Pershing Counties, Nevada from all forms of appropriation under the public land laws, including location and entry under the United States mining laws, and leasing under the mineral and geothermal leasing laws, subject to valid existing rights, for four years for land management evaluation purposes. In addition, 68,809.44 acres of Federal land in the Dixie Valley area (Churchill County, Nevada) are withdrawn from leasing under the mineral leasing laws. Including the 8,722.47 acres of Department of the Navy (DON) lands, the total Federal land withdrawn by this Public Land Order is 772,370.75 acres. Non-Federal lands totaling 66,160.53 acres are described within the withdrawal area. Any current or future Federal estate interest in these non-Federal lands are subject to this withdrawal.
This Public Land Order takes effect on August 31, 2018.
Colleen Dingman, BLM, Carson City District Office, 775-885-6168; address: 5665 Morgan Mill Rd., Carson City, NV 89701; email:
This withdrawal keeps the lands identified below from the specified forms of appropriation in order to maintain the current environmental baseline, relative to mineral exploration and development for land management evaluation, subject to valid existing rights, to allow the DON time to complete its environmental evaluations under the National Environmental Policy Act (NEPA). The DON's environmental evaluations and NEPA analysis are for a potential legislative withdrawal of these acres of land at Naval Air Station Fallon that the DON intends to propose to Congress to withdraw and reserve for military use.
By virtue of the authority vested in the Secretary of the Interior by Section 204 of the Federal Land Policy and Management Act of 1976, 43 U.S.C. 1714, it is ordered as follows:
1. Subject to valid existing rights, the following described public lands are hereby
Mining Claim Nos: NMC1025588 thru NMC1025706, NMC108333 thru NMC1083361, NMC139460, NMC139462 thru NMC139464, NMC139486 thru NMC 139491, NMC144261, NMC144262, NMC186865, NMC186866, NMC3100915, NMC310918, NMC44931 thru NMC449940, and NMC804403; Millsite Nos: NMC1090926 thru NMC1090931.
The area described for lands adjoining the Naval Air Station Fallon's B-16 aggregates 32,201.17 acres in Churchill and Lyon Counties.
The area described for lands adjoining the Naval Air Station Fallon's B-17 training range aggregates 253,089.11 acres in Churchill, Nye, and Mineral Counties.
The area described for lands adjoining the Naval Air Station Fallon's B-20 training range aggregates 49,986.79 acres in Churchill and Pershing Counties.
The area described for lands adjoining the Naval Air Station Fallon's B-20 training range aggregates 65,375.88 acres in Churchill County.
The area described for lands adjoining the Naval Air Station Fallon's B-20 training range aggregates 3,201.00 acres in Churchill County.
The area described for lands adjoining the Dixie Valley Training Area aggregates 290,984.89 acres in Churchill and Mineral Counties.
The area described for lands adjoining the Dixie Valley Training Area aggregates 8,722.47 acres in Churchill and Mineral Counties.
2. Subject to valid existing rights, the following described public lands are hereby withdrawn from leasing under the mineral leasing laws to maintain current environmental baseline conditions:
The area described for Dixie Valley Training Area aggregates 68,809.44 acres in Churchill County.
3. Subject to valid existing rights, the following described non-Federal lands are hereby withdrawn from all forms of appropriation under the public land laws, including location and entry under the United States mining laws, and leasing under the mineral and geothermal leasing laws to maintain current environmental baseline conditions:
The area described for lands adjoining the Naval Air Station Fallon's B-17 training range aggregates 2,037.37 acres in Churchill, Nye, and Mineral Counties.
The area described for lands adjoining the Naval Air Station Fallon's B-20 training range aggregates 61,764.88 acres in Churchill and Pershing Counties.
The area described for lands adjoining the Dixie Valley Training Area aggregates 2,358.28 acres in Churchill and Mineral Counties.
4. The withdrawal made by this Order does not alter the applicability of those public land laws governing the use of the land under lease, license, or permit, or governing the disposal of the mineral or vegetative resources other than under the mining or mineral leasing laws.
5. This withdrawal will expire four years from the effective date of this order, unless, as a result of a review conducted pursuant to Section 204(f) of the Federal Land Policy and Management Act of 1976, 43 U.S.C. 1714(f), the Secretary determines that the withdrawal shall be extended.
Bureau of Land Management, Interior.
Notice of error and extension of public comment period.
This action corrects an error related to potential disposal of Federal lands under the Federal Land Policy and Management Act, as amended (FLPMA), within a notice published in the
The BLM is extending the public comment period by 15 days to provide for notice of and opportunity to comment on the modified Draft RMPs and EIS. Comments should be submitted by November 30, 2018.
You may submit comments on the modified Draft RMPs and EIS by either of the following methods:
•
•
Copies of the modified Draft RMPs and EIS are available at the following locations:
• Bureau of Land Management, Utah State Office, 440 West 200 South, Suite 500, Salt Lake City, Utah.
• Escalante Interagency Visitor Center, 755 West Main, Escalante, Utah.
• Kanab Field Office, 669 South Highway 89A, Kanab, Utah.
The modified Draft RMPs and EIS and accompanying errata sheet are available on the ePlanning website at:
Matt Betenson, Associate Monument Manager, telephone (435) 644-1200; address 669 S Hwy. 89A, Kanab, UT 84741; email
On December 4, 2017, President Trump signed Presidential Proclamation 9682 modifying the boundaries of the GSENM as established by Proclamation 6920 to exclude from designation and reservation approximately 861,974 acres of land. Lands that are excluded from the Monument boundaries are now referred to as the Kanab-Escalante Planning Area and are managed in accordance with the BLM's multiple-use mandate.
The Draft EIS noticed in the
The modified Draft RMPs and EIS and an accompanying errata sheet that includes a summary of all of the changes made will be distributed to stakeholders and is available on the BLM's ePlanning website at:
The BLM is soliciting comments on the entire modified Draft RMPs and EIS. All comments received by the BLM subsequent to the notice of availability for the Draft RMPs and EIS on August 17, 2018, but prior to publication of this notice, will be included in the project record and considered by the agency in preparation of the Final RMPs and EIS. Please note that public comments and information submitted, including names, street addresses, and email addresses of persons who submit comments, will be available for public review and disclosure at the addresses provided in the
Before including your address, phone number, email address, or other personally identifiable information in your comment, you should be aware that your entire comment—including your personally identifiable information—may be made publicly available at any time. While you may request that the BLM withhold your personally identifiable information from public review, we cannot guarantee that we will be able to do so.
40 CFR 1506.6, 40 CFR 1506.10, and 43 CFR 1610.2.
Bureau of Land Management, Interior.
Notice of availability.
In compliance with the National Environmental Policy Act of 1969 (NEPA), as amended, and the Federal Land Policy and Management Act of 1976 (FLPMA), as amended, the Bureau of Land Management (BLM), Arizona State Office, Phoenix, Arizona, has prepared a Draft Environmental Impact Statement (EIS) for the proposed Ten West Link 500-kilovolt (kV) Transmission Line Project (Project) and Draft Resource Management Plan (RMP) Amendments to the Yuma Field Office RMP and the California Desert Conservation Area Plan. By this notice, the BLM is announcing the opening of the public comment period on the Draft EIS/Draft RMP Amendments.
To ensure that comments will be considered, the BLM must receive written comments on the Draft EIS and Draft RMP Amendments within 90 days following the date the Environmental Protection Agency publishes its Notice of Availability in the
You may submit comments related to the Project by any of the following methods:
•
•
•
•
Copies of the Draft EIS/Draft RMP Amendments are available at the BLM's eplanning website:
Lane Cowger, Project Manager, telephone: 602-417-9612; address: BLM, Arizona State Office, One North Central Avenue, Suite 800, Phoenix, AZ 85004; email:
DCR Transmission, LLC, has filed a right-of-way (ROW) application with the BLM pursuant to Title V of FLPMA, proposing to construct, operate, maintain, and decommission a single-circuit alternating current 500-kV overhead transmission line. The Project would provide a connection between the existing Delaney Substation in Tonopah, Arizona, and the existing Colorado River Substation in Blythe, California. The project purpose is to strengthen the electrical grid and improve reliability.
DCR Transmission has filed an application for a Certificate of Public Convenience and Necessity (CPCN) with the California Public Utilities Commission (CPUC) to site the transmission infrastructure in California. The CPUC approval or denial of the CPCN application is a discretionary decision. Under California law, the CPUC would be required to comply with the California Environmental Quality Act (CEQA) before issuing the CPCN. The CPUC is currently a cooperating agency in the BLM's NEPA analysis. Pursuant to the California Code of Regulations Title 14 Section 15121, the CPUC will rely upon this EIS to comply with CEQA.
An interdisciplinary approach was used to develop the Draft EIS. The issues addressed in the Draft EIS that shaped the Project's scope and alternatives include, but are not limited to: Air and climate, biological resources, cultural resources, CEQA, health and safety, noise, land use (including farmlands and military operations), recreation, socioeconomics and environmental justice, special designations, wilderness and wilderness characteristics, trails, visual resources, and transportation.
Based on feedback from cooperating agencies, stakeholders, and public scoping, the BLM developed and analyzed a suite of alternatives, which are detailed in the Draft EIS. The BLM has identified Alternative 2: BLM Utility Corridor Route, with minor route modifications near the Town of Quartzsite, Arizona, as the Agency-Preferred Alternative route for the proposed transmission line. This route is 124.9 miles long and primarily located within existing BLM utility corridors or parallel to existing infrastructure. This route is responsive to stakeholder input, by minimizing impacts to the Yuma Proving Ground, avoiding the Kofa National Wildlife Refuge, Johnson Canyon, the Colorado River Indian Tribes Reservation, the Long Term Visitor Area (recreation area), and the Ehrenberg Sandbowl area; avoiding residential and other development south of the City of Blythe and minimize use of private land in California; avoiding an area of dense cultural resources south of the City of Blythe; and crossing a majority of Visual Resource Management (VRM) Class III land. This route also provides interconnections for potential future energy development opportunities in Arizona.
The Agency-Preferred Alternative would require an amendment to the Yuma RMP to: (1) Designate approximately 13.5 miles of 200-foot wide ROW on public lands managed by the BLM outside of designated utility corridors; and (2) Change the existing VRM Class designations from Class III to Class IV within 0.3-mile either side of centerline of 18.4 miles, for a total of 6,803.2 acres. The Agency-Preferred Alternative would also require an amendment to the California Desert Conservation Area Plan to authorize construction within 0.25-mile of occurrences of Harwood's eriastrum, a BLM special status plant species.
Hardcopies of the documents can be reviewed at the Arizona State Office (see
The BLM will use the NEPA public participation requirements to assist the agency in satisfying the public-involvement requirements under Section 106 of the National Historic Preservation Act (NHPA) (54 U.S.C. 306108) pursuant to 36 CFR 800.2(d)(3).
The information about historic and cultural resources within the area potentially affected by the Project will assist the BLM in identifying and evaluating impacts to such resources in the context of both the NEPA and Section 106 of the NHPA.
The BLM will continue consultation with Indian tribes on a government-to-government basis in accordance with Executive Order 13175 and other policies. Tribal concerns, including impacts on Indian trust assets and potential impacts to cultural resources, will be given due consideration.
Before including your address, phone number, email address, or other personal identifying information in your comment, you should be aware that your entire comment—including your personal identifying information—may be made publicly available at any time. While you can ask us in your comment to withhold your personal identifying information from public review, we cannot guarantee that we will be able to do so.
40 CFR 1506.6(b) and 43 CFR 1610.2.
National Park Service, Interior.
Notice.
The National Park Service is soliciting comments on the significance of properties nominated before August 18, 2018, for listing or related actions in the National Register of Historic Places.
Comments should be submitted by September 17, 2018.
Comments may be sent via U.S. Postal Service and all other carriers to the National Register of Historic Places, National Park Service, 1849 C St. NW, MS 7228, Washington, DC 20240.
The properties listed in this notice are being considered for listing or related actions in the National Register of Historic Places. Nominations for their consideration were received by the National Park Service before August 18, 2018. Pursuant to Section 60.13 of 36 CFR part 60, written comments are being accepted concerning the
Before including your address, phone number, email address, or other personal identifying information in your comment, you should be aware that your entire comment—including your personal identifying information—may be made publicly available at any time. While you can ask us in your comment to withhold your personal identifying information from public review, we cannot guarantee that we will be able to do so.
Nominations submitted by State Historic Preservation Officers:
A request for removal has been made for the following resource:
Additional documentation has been received for the following resources:
Nomination submitted by Federal Preservation Officer:
The State Historic Preservation Officer reviewed the following nominations and responded to the Federal Preservation Officer within 45 days of receipt of the nominations and supports listing the property in the National Register of Historic Places.
Section 60.13 of 36 CFR part 60.
Office of the Secretary, Office of Natural Resources Revenue, Interior.
Notice of information collection; request for comment.
In accordance with the Paperwork Reduction Act of 1995, we, the Office of Natural Resources Revenue (ONRR), are proposing to renew an information collection.
You must submit your written comments on or before October 30, 2018.
You may submit comments on this ICR to ONRR by using one of the following three methods (please reference “ICR 1012-0004” in the subject line of your comments):
1. Electronically go to
2. Mail comments to Mr. Armand Southall, Regulatory Specialist, ONRR, P.O. Box 25165, MS 64400B, Denver, Colorado 80225-0165.
3. Hand-carry or mail comments, using an overnight courier service, to ONRR. Our courier address is Building 85, Entrance N-1, Denver Federal Center, West 6th Ave. and Kipling St., Denver, Colorado 80225.
For questions on technical issues, contact Ms. Lee-Ann Martin, Program Manager, Reference and Reporting Management, ONRR, telephone (303) 231-3313, or email
In accordance with the Paperwork Reduction Act of 1995, we provide the general public and other Federal agencies with an opportunity to comment on new, proposed, revised, and continuing collections of information. This helps us assess the impact of our information collection requirements and minimize the public's reporting burden. It also helps the public understand our information collection requirements and provide the requested data in the desired format.
We are soliciting comments on the proposed ICR that is described below. We are especially interested in public comment addressing the following issues mentioned in the OMB regulations at 5 CFR 1320.8(d)(1): (1) Is the collection necessary to the proper functions of ONRR; (2) will this information be processed and used in a timely manner; (3) is the estimate of burden accurate; (4) how might ONRR enhance the quality, utility, and clarity of the information to be collected; and (5) how might ONRR minimize the burden of this collection on the respondents, including through the use of information technology.
Comments that you submit in response to this notice are a matter of public record. ONRR will post all comments, including names and addresses of respondents at
Information collections that we cover in this ICR are found at title 30 CFR part 1210, subparts B, C, and D, which pertain to reporting oil, gas, and geothermal resources royalties and oil and gas production; and part 1212, subpart B, which pertains to recordkeeping.
When a company or an individual enters into a lease to explore, develop, produce, and dispose of minerals from Federal or Indian lands, that company or individual agrees to pay the lessor a share in an amount or value of production from the leased lands. The lessee, or its designee, must report various kinds of information to the lessor relative to the disposition of the leased minerals. Such information is available within the records of the lessee or others involved in developing, transporting, processing, purchasing, or selling such minerals. The information that ONRR collects includes data necessary to ensure that the lessee accurately values and appropriately pays all royalties and other mineral revenues due.
Reporters submit information into the ONRR financial accounting system that includes royalty, rental, bonus, and other payment information; sales volumes and values; and other royalty values. ONRR uses the accounting system to compare production volumes with royalty volumes to verify that companies reported and paid proper royalties for the minerals produced. Additionally, we share the data electronically with the Bureau of Safety and Environmental Enforcement, Bureau of Ocean Energy Management, Bureau of Land Management, Bureau of Indian Affairs, and Tribal and State governments so that they can perform their land and lease management responsibilities.
We use the information collected in this ICR to ensure that companies properly pay royalties based on accurate production accounting on oil, gas, and geothermal resources that they produce from Federal and Indian leases. Production data is also used to determine whether a lease is producing in paying quantities and therefore has not expired, and to track total production from Federal and Indian lands by lease, communitization agreement, unit, field or area, State, reservation, and nationally. The requirement to report accurately and timely is mandatory. Please refer to the chart for all reporting requirements and associated burden hours.
Payors (Reporters) must report, according to various regulations, and remit royalties on oil, gas, and geothermal resources that they produced from leases on Federal and Indian lands. The reporters use the following form for royalty reporting:
Operators (Reporters) must submit, according to various regulations, production reports if they operate a Federal or Indian onshore or offshore oil and gas lease or federally approved unit or communitization agreement. We use the ONRR financial accounting system to track minerals produced from Federal and Indian lands, from the point of production to the point of disposition or royalty determination and/or point of sale. The reporters use the following forms for production accounting and reporting:
We are requesting OMB's approval to continue to collect this information. Not collecting this information would limit the Secretary's ability to discharge fiduciary duties and may also result in the loss of royalty payments. ONRR protects the proprietary information that it receives, and does not collect items of a sensitive nature. It is mandatory that the reporters submit forms ONRR-2014, ONRR-4054, and ONRR-4058.
We have not included in our estimates certain requirements that companies perform in the normal course of business that ONRR considers usual and customary. We display the estimated annual burden hours by CFR section and paragraph in the following chart.
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.
Paperwork Reduction Act of 1995 (44 U.S.C. 3501
Office of the Secretary, Office of Natural Resources Revenue, Interior.
Notice of proposed modifications; request for comments.
The Office of Natural Resources Revenue (ONRR) is inviting comments on proposed modifications to the list of existing market centers that royalty payors use to value oil produced from Federal leases. This proposed modification is applicable to those valuing Federal oil production using NYMEX prices or ANS spot prices.
You must submit your written comments on or before October 1, 2018.
You may submit comments on this notice to ONRR by using one of the following three methods. Please reference “ONRR-2018-0002” in your comments.
• Electronically go to
• Mail comments to Mr. Armand Southall, Regulatory Specialist, ONRR, P.O. Box 25165, MS 64400B, Denver, Colorado 80225-0165.
• Hand-carry or mail comments using an overnight courier service to ONRR. Our courier address is Building 85, Entrance N-1, Denver Federal Center, West 6th Avenue and Kipling Street, Denver, Colorado 80225. Visitor parking is available in the north parking lot near Entrance N-1, which is the only
For questions on technical issues, contact Mr. Robert Sudar, Market and Spatial Analytics, CEVA, ONRR, telephone (303) 231-3511 or email to
ONRR publishes a list of market centers for use in Federal oil valuation calculations under 30 CFR 1206.112. This regulation applies to payors who are applying adjustments and transportation allowances when Federal oil production is valued using NYMEX prices or ANS spot prices. Under § 1206.113, ONRR will monitor market activity and, if necessary, add to or modify the list of market centers. ONRR last published the list of market centers in the
1. Points where ONRR-approved publications publish prices useful for index purposes;
2. Markets served;
3. Input from Industry and others knowledgeable in crude oil marketing and transportation;
4. Simplification; and
5. Other relevant matters.
ONRR is seeking comments on its proposal to modify the list of market centers and the oil types at each location as listed below:
For supplementary information on these proposed market center locations, please visit
Before making this proposal final, ONRR seeks comments. We are especially interested in comments from Industry and others knowledgeable in crude oil marketing and transportation that addresses the following issues: (1) Whether ONRR should reconsider the proposed new market centers based on the five factors specified in § 1206.113; (2) whether ONRR should reconsider removing the market centers proposed for removal based on the five factors specified in § 1206.113; (3) whether ONRR should reconsider modifying or removing the market centers proposed to remain unchanged based on the five factors specified in § 1206.113; and (4) whether ONRR should consider adding any other market centers based on the five factors specified in § 1206.113.
ONRR will post all comments, including names and addresses of respondents at
30 CFR 1206.113.
Bureau of Ocean Energy Management, Interior.
Notice of availability of the Final Environmental Impact Statement.
The Bureau of Ocean Energy Management (BOEM) is announcing the availability of the Final Environmental Impact Statement (FEIS) for the Liberty Development and Production Plan (DPP) in the Beaufort Sea Planning Area. The FEIS analyzes the potential environmental impacts of the proposed action described in the Liberty DPP and reasonable alternatives to the proposed action.
Electronic copies of the FEIS and associated information is available on BOEM's website at:
Lauren Boldrick, Project Manager, Bureau of Ocean Energy Management, Alaska OCS Region, 3801 Centerpoint Drive, Suite 500, Anchorage, Alaska 99503, 907-334-5200.
The proposed action would recover and process oil from the Liberty oil field and transport sales-quality oil to market. To accomplish this, Hilcorp Alaska LLC would construct the Liberty Drilling and Production Island (LDPI) to recover reserves from three Federal leases (OCS-Y-1585, OCS-Y-1650, and OCS-Y-1886) in Foggy Island Bay of the Beaufort Sea. The ocean bottom footprint of the proposed LDPI is approximately 24 acres. Hilcorp would construct a new pipeline linking the LDPI to the Badami Sales Oil Pipeline (Badami pipeline). They would bury the subsea portion (approximately 5.6 miles) of the pipeline along a route running south from the LPDI to the Alaska coastline west of the Kadleroshilik River. The pipeline would transition to above-ground for approximately 1.5 miles and tie into the existing Badami pipeline. Hilcorp would produce and process oil from the LDPI, transport it through the Badami pipeline to the existing common carrier pipeline system, and from there on to the Trans-Alaska Pipeline System.
The full text of the mitigation measures which will be included in the project approval are available in the Liberty DPP FEIS. The FEIS and associated information is available on BOEM's website at:
Bureau of Reclamation, Interior.
Notice of information collection; request for comment.
In accordance with the Paperwork Reduction Act of 1995, we, the Bureau of Reclamation (Reclamation), are proposing to renew an information collection.
Interested persons are invited to submit comments on or before October 30, 2018.
Send written comments on this information collection request (ICR) by mail to Paul Matuska, Water Accounting and Verification Group Manager, LC-4200, Bureau of Reclamation, Lower Colorado Regional Office, P.O. Box 61470, Boulder City, NV 89006-1470; or by email to
To request additional information about this ICR, contact Paul Matuska by email
In accordance with the Paperwork Reduction Act of 1995, we provide the general public and other Federal agencies with an opportunity to comment on new, proposed, revised, and continuing collections of information. This helps us assess the impact of our information collection requirements and minimize the public's reporting burden. It also helps the public understand our information collection requirements and provide the requested data in the desired format.
We are soliciting comments on the proposed ICR that is described below. We are especially interested in public comment addressing the following issues: (1) Is the collection necessary to the proper functions of Reclamation; (2) will this information be processed and used in a timely manner; (3) is the estimate of burden accurate; (4) how might Reclamation enhance the quality, utility, and clarity of the information to be collected; and (5) how might Reclamation minimize the burden of this collection on the respondents, including through the use of information technology.
Comments that you submit in response to this notice are a matter of public record. We will include or summarize each comment in our request to OMB to approve this ICR. Before including your address, phone number, email address, or other personal identifying information in your comment, you should be aware that your entire comment—including your personal identifying information—may be made publicly available at any time. While you can ask us in your comment to withhold your personal identifying information from public review, we cannot guarantee that we will be able to do so.
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 authority for this action is the Paperwork Reduction Act of 1995 (44 U.S.C. 3501
This document was received for publication by the Office of the Federal Register on August 27, 2018.
U.S. International Trade Commission.
Notice.
Notice is hereby given that the presiding administrative law judge has issued a Final Initial Determination and Recommended Determination on Remedy and Bonding in the above-captioned investigation. The Commission is soliciting comments on public interest issues raised by the recommended relief, specifically a limited exclusion order and cease and desist orders. This notice is soliciting public interest comments from the public only. Parties are to file public interest submissions pursuant to Commission rules.
Sidney A. Rosenzweig, Esq., Office of the General Counsel, U.S. International Trade Commission, 500 E Street SW, Washington, DC 20436, telephone (202) 708-2532. The public version of the
General information concerning the Commission may also be obtained by accessing its internet server (
Section 337 of the Tariff Act of 1930 provides that if the Commission finds a violation it shall exclude the articles concerned from the United States:
The Commission is interested in further development of the record on the public interest in these investigations. Accordingly, parties are to file public interest submissions pursuant to pursuant to 19 CFR 210.50(a)(4). In addition, members of the public are hereby invited to file submissions of no more than five (5) pages, inclusive of attachments, concerning the public interest in light of the administrative law judge's Recommended Determination on Remedy and Bonding issued in this investigation on July 23, 2018. Comments should address whether issuance of a limited exclusion order and cease and desist orders in this investigation directed to respondents' LiSi Press products would affect the public health and welfare in the United States, competitive conditions in the United States economy, the production of like or directly competitive articles in the United States, or United States consumers.
In particular, the Commission is interested in comments that:
(i) Explain how the articles potentially subject to the recommended orders are used in the United States;
(ii) identify any public health, safety, or welfare concerns in the United States relating to the recommended orders;
(iii) identify like or directly competitive articles that complainant, its licensees, or third parties make in the United States which could replace the subject articles if they were to be excluded;
(iv) indicate whether complainant, complainant's licensees, and/or third party suppliers have the capacity to replace the volume of articles potentially subject to the recommended exclusion order and/or a cease and desist order within a commercially reasonable time; and
(v) explain how the limited exclusion order and cease and desist orders would impact consumers in the United States.
Written submissions from the public must be filed no later than by close of business on September 13, 2018.
Persons filing written submissions must file the original document electronically on or before the deadlines stated above and submit 8 true paper copies to the Office of the Secretary by noon the next day pursuant to section 210.4(f) of the Commission's Rules of Practice and Procedure (19 CFR 210.4(f)). Submissions should refer to the investigation number (“Inv. No. 337-TA-1050”) in a prominent place on the cover page and/or the first page. (
Any person desiring to submit a document to the Commission in confidence must request confidential treatment. All such requests should be directed to the Secretary to the Commission and must include a full statement of the reasons why the Commission should grant such treatment.
The authority for the Commission's determination is contained in section 337 of the Tariff Act of 1930, as amended (19 U.S.C. 1337), and in Part 210 of the Commission's Rules of Practice and Procedure (19 CFR part 210).
By order of the Commission.
Notice of application.
Registered bulk manufacturers of the affected basic classes, and applicants therefore, may file written comments on or objections to the issuance of the proposed registration on or before October 30, 2018.
Written comments should be sent to: Drug Enforcement Administration, Attention: DEA Federal Register Representative/DRW, 8701 Morrissette Drive, Springfield, Virginia 22152.
The Attorney General has delegated his authority under the Controlled Substances Act to the Administrator of the Drug Enforcement Administration (DEA), 28 CFR 0.100(b). Authority to exercise all necessary functions with respect to the promulgation and implementation of 21 CFR part 1301, incident to the registration of manufacturers, distributors, dispensers, importers, and exporters of controlled substances (other than final orders in connection with suspension, denial, or revocation of registration) has been redelegated to the Assistant Administrator of the DEA Diversion Control Division pursuant to section 7 of 28 CFR part 0, appendix to subpart R.
In accordance with 21 CFR 1301.33(a), this is notice that on July 6, 2018, National Center for Natural Products Research NIDA MPROJECT, University of Mississippi, 135 Coy Waller Complex, P.O. Box 1848, University, Mississippi 38677-1848 applied to be registered as a bulk manufacturer of the following basic classes of controlled substances:
The company plans to bulk manufacture the listed controlled substances to make available to the National Institute on Drug Abuse (NIDA) a supply of bulk marihuana for distribution to research investigators in support of the national research program needs. No other activities for these drug codes are authorized for this registration.
In accordance with Departmental Policy, 28 CFR 50.7, notice is hereby given that a proposed Consent Decree in
This proposed Consent Decree concerns a complaint filed by the United States against Defendants Richard M. Osborne, Sr., Great Plains Exploration, LLC, Center Street Investments, Inc., Callendar Real Estate Development Company, LLC, and Osair, Inc., pursuant to Sections 301(a), 309(b), and 309(d) of the Clean Water Act, 33 U.S.C. 1311(a), 1319(b), and 1319(d), to obtain injunctive relief from and impose civil penalties against the Defendants for violating the Clean Water Act by discharging pollutants without a permit into waters of the United States. The proposed Consent Decree resolves these allegations by requiring the Defendants to mitigate for the harms caused by the impacted areas.
The Department of Justice will accept written comments relating to this proposed Consent Decree for thirty (30) days from the date of publication of this Corrected Notice. Please address comments to Phillip R. Dupré, United State Department of Justice, Environment and Natural Resources Division, Post Office Box 7611, Washington, DC 20044-7611 and refer to
The proposed Consent Decree may be examined at the Clerk's Office, United States District Court for the Northern District of Ohio, Carl B. Stokes United States Courthouse, 801 West Superior Avenue, Cleveland, OH 44113. In addition, the proposed Consent Decree may be examined electronically at
Wage and Hour Division, Department of Labor,
Notice.
The Department of Labor (DOL) is soliciting comments concerning a proposed extension to the information collection request (ICR) titled, “Work-Study Program of the Child Labor Regulations.” This comment request is part of continuing Departmental efforts to reduce paperwork and respondent burden in accordance with the Paperwork Reduction Act of 1995 (PRA), 44 U.S.C. 3501
This program helps to ensure that requested data can be provided in the desired format, reporting burden (time and financial resources) is minimized, collection instruments are clearly understood, and the impact of collection requirements on respondents can be properly assessed. A copy of the proposed information request can be obtained by contacting the office listed below in the
Written comments must be submitted to the office listed in the
You may submit comments identified by Control Number 1235-0024, by either one of the following methods:
Robert Waterman, Compliance Specialist, Division of Regulations, Legislation, and Interpretation, Wage and Hour Division, U.S. Department of Labor, Room S-3502, 200 Constitution Avenue NW, Washington, DC 20210; telephone: (202) 693-0406 (this is not a toll-free number). Copies of this notice may be obtained in alternative formats (Large Print, Braille, Audio Tape, or Disc), upon request, by calling (202) 693-0023 (not a toll-free number). TTY/TTD callers may dial toll-free (877) 889-5627 to obtain information or request materials in alternative formats.
• Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
• Enhance the quality, utility, and clarity of the information to be collected;
• Evaluate the accuracy of the agency's estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
• Minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
National Science Foundation.
Submission for OMB review; comment request.
The National Science Foundation (NSF) has submitted the following information collection requirement to OMB for review and clearance under the Paperwork Reduction Act of 1995. This is the second notice for public comment; the first was published in the
The National Science Foundation (NSF) is announcing plans to request renewed clearance of this collection. The primary purpose of this revision is to implement changes described in the Supplementary Information section of this notice. Comments regarding (a) whether the collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility; (b) the accuracy of the agency's estimate of burden including the validity of the methodology and assumptions used; (c) ways to enhance the quality, utility and clarity of the information to be collected; (d) ways to minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology should be addressed to: Office of Information and Regulatory Affairs of OMB, Attention: Desk Officer for National Science Foundation, 725 17th Street NW, Room 10235, Washington, DC 20503, and to Suzanne H. Plimpton, Reports Clearance Officer, National Science Foundation, 2415 Eisenhower Avenue, Alexandria, VA 22314, or send email to
Comments regarding these information collections are best assured of having their full effect if received within 30 days of this notification. Copies of the submission(s) may be obtained by calling 703-292-7556.
NSF may not conduct or sponsor a collection of information unless the collection of information displays a currently valid OMB control number and the agency informs potential persons who are to respond to the collection of information that such persons are not required to respond to the collection of information unless it displays a currently valid OMB control number.
The draft NSF PAPPG was made available for review by the public on the NSF website at
“To promote the progress of science; to advance the national health, prosperity, and welfare; to secure the national defense. . . .”
The Act authorized and directed NSF to initiate and support:
• Basic scientific research and research fundamental to the engineering process;
• Programs to strengthen scientific and engineering research potential;
• Science and engineering education programs at all levels and in all the various fields of science and engineering;
• Programs that provide a source of information for policy formulation; and
• Other activities to promote these ends.
NSF's core purpose resonates clearly in everything it does: Promoting achievement and progress in science and engineering and enhancing the potential for research and education to contribute to the Nation. While NSF's
Support is made primarily through grants, contracts, and other agreements awarded to approximately 2,000 colleges, universities, academic consortia, nonprofit institutions, and small businesses. The awards are based mainly on merit evaluations of proposals submitted to the Foundation.
The Foundation has a continuing commitment to monitor the operations of its information collection to identify and address excessive reporting burdens as well as to identify any real or apparent inequities based on gender, race, ethnicity, or disability of the proposed principal investigator(s)/project director(s) or the co-principal investigator(s)/co-project director(s).
It has been estimated that the public expends an average of approximately 120 burden hours for each proposal submitted. Since the Foundation expects to receive approximately 50,600 proposals in FY 2019, an estimated 6,072,000 burden hours will be placed on the public.
The Foundation has based its reporting burden on the review of approximately 50,600 new proposals expected during FY 2019. It has been estimated that anywhere from one hour to 20 hours may be required to review a proposal. We have estimated that approximately 5 hours are required to review an average proposal. Each proposal receives an average of 3 reviews, resulting in approximately 759,000 hours per year.
The information collected on the reviewer background questionnaire (NSF 428A) is used by managers to maintain an automated database of reviewers for the many disciplines represented by the proposals submitted to the Foundation. Information collected on gender, race, and ethnicity is used in meeting NSF needs for data to permit response to Congressional and other queries into equity issues. These data also are used in the design, implementation, and monitoring of NSF efforts to increase the participation of various groups in science, engineering, and education. The estimated burden for the Reviewer Background Information (NSF 428A) is estimated at 5 minutes per respondent with up to 10,000 potential new reviewers for a total of 833 hours.
The aggregate number of burden hours is estimated to be 6,831,000. The actual burden on respondents has not changed.
The National Science Board, pursuant to NSF regulations (45 CFR part 614), the National Science Foundation Act, as amended, (42 U.S.C. 1862n-5), and the Government in the Sunshine Act (5 U.S.C. 552b), hereby gives notice of a revision to an announcement of meetings for the transaction of National Science Board business.
83 FR 43710, published on August 27, 2018.
Thursday, August 30, 2018 from 3:00 p.m. to 4:00 p.m.
This meeting of the National Science Board has been postponed. Notice of the new time and place will be provided when it is rescheduled.
Brad Gutierrez,
In accordance with the purposes of Sections 29 and 182b of the Atomic Energy Act (42 U.S.C. 2039, 2232b), the Advisory Committee on Reactor Safeguards (ACRS) will hold meetings on October 4-6, 2018, Three White Flint North, 11601 Landsdown Street, North Bethesda, MD 20852.
Procedures for the conduct of and participation in ACRS meetings were published in the
Thirty-five hard copies of each presentation or handout should be provided 30 minutes before the meeting. In addition, one electronic copy of each presentation should be emailed to the Cognizant ACRS Staff one day before meeting. If an electronic copy cannot be provided within this timeframe, presenters should provide the Cognizant ACRS Staff with a CD containing each presentation at least 30 minutes before the meeting.
In accordance with Subsection 10(d) of Public Law 92-463 and 5 U.S.C. 552b(c), certain portions of this meeting may be closed, as specifically noted above. Use of still, motion picture, and television cameras during the meeting may be limited to selected portions of the meeting as determined by the Chairman. Electronic recordings will be permitted only during the open portions of the meeting.
ACRS meeting agendas, meeting transcripts, and letter reports are available through the NRC Public Document Room at
Video teleconferencing service is available for observing open sessions of ACRS meetings. Those wishing to use this service should contact Mr. Theron Brown, ACRS Audio Visual Technician (301-415-6702), between 7:30 a.m. and 3:45 p.m. (ET), at least 10 days before the meeting to ensure the availability of this service. Individuals or organizations requesting this service will be responsible for telephone line charges and for providing the equipment and facilities that they use to establish the video teleconferencing link. The availability of video teleconferencing services is not guaranteed.
Nuclear Regulatory Commission.
10 CFR 2.206 request; receipt.
The U.S. Nuclear Regulatory Commission (NRC) is giving notice that by petition dated March 27, 2018, Environmental Law and Policy Center (ELPC) (the petitioner) has requested that the NRC take enforcement action with regard to First Energy Corp. (FE), First Energy Solutions (FES), FirstEnergy Nuclear Generation (NG), and FirstEnergy Nuclear Operating Company (FENOC). The petitioner's requests are included in the
Please refer to Docket ID NRC-2018-0174 when contacting the NRC about the availability of information regarding this document. You may obtain publicly-available information related to this document using any of the following methods:
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Bhalchandra K. Vaidya, Office of Nuclear Reactor Regulation, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001; telephone: 301-415-3308; email:
On March 27, 2018, the petitioner requested that the NRC take enforcement action with regard to FE, FES, NG, and FENOC operations in Ohio and Pennsylvania at Beaver Valley Power Station (BVPS), Units 1 and 2; Davis-Besse Nuclear Power Station (DBNPS), Unit 1; and Perry Nuclear Power Plant (PNPP), Unit 1 (ADAMS Accession No. ML18094A642). The petitioner requested that the NRC take the following actions:
(1) Promptly issue a Demand for Information to FE, FES, NG, and FENOC requesting site-specific decommissioning funding plans for the BVNPS, DBNPS, and PNPP;
(2) Promptly issue a Demand for Information to FE, FES, NG, and FENOC regarding their reliance on external trust funds from FE and FES to satisfy their decommissioning financial obligations;
(3) Promptly issue a Demand for Information to FE, FES, NG, and FENOC regarding their continued reliance on Parent Guarantees from FE to satisfy decommissioning funding obligations, including the ability of FE to satisfy the Parent Guarantee financial test under title 10 of the
(4) Promptly issue a Demand for Information to FES, NG, and FENOC to the extent that they are relying on Parent Guarantees from FES to satisfy decommissioning funding obligations, including the ability of FES to satisfy the Parent Guarantee financial test under 10 CFR part 30, appendix A;
(5) Promptly issue a Demand for Information to FE, FES, NG, and FENOC regarding their proposed investment and financial contribution plans to make up the current decommissioning shortfall; and
(6) Promptly issue a Demand for Information to FE and FES, respectively, regarding each of their commitments to guarantee NG and FENOC's decommissioning shortfall in the event of bankruptcy.
(1) Promptly issue a Notice of Violation against FE, FES, NG, and FENOC for operating nuclear facilities without sufficient decommissioning funds in violation of 42 United States Code Annotated (U.S.C.A.), Section 2201(x)(1) and 10 CFR 50.75;
(2) Promptly issue civil penalties against FE, FES, NG, and FENOC for operating nuclear facilities without sufficient decommissioning funds in violation of 42 U.S.C.A. Section 2201(x)(1) and 10 CFR 50.75; and
(3) Promptly issue an Order to suspend NG, and FENOC's licenses for BVNPS, DBNPS, and PNPP.
The ELPC also urges the NRC to prohibit NG and FENOC from placing their nuclear facilities into SAFSTOR for purely financial reasons. In addition, ELPC requests that this Petition be given immediate emergency consideration in light of FE's and FES' rapidly deteriorating financial conditions.
The basis for ELPC's request is summarized below:
1. NG and FENOC's decommissioning trust amounts are insufficient on their own to provide reasonable assurance of funding.
2. FE cannot rely on rate increases forced on retail ratepayers to pay for the decommissioning trust fund shortfalls.
3. The costs, including SAFSTOR costs, may still be much higher than expected due to significantly higher shortfalls as reported by the Callan Institute and recognized flaws in the NRC's cost estimate formula.
4. On March 28, 2018, FES and FENOC announced that they would permanently retire all four of their reactors within the next 3 years. If plants close in 2020 and 2021, the funds cannot grow to levels that will pay for complete decommissioning.
5. Parent companies FE and FES filed for bankruptcy on March 31, 2018.
The request is being treated pursuant to 10 CFR 2.206 of the Commission's regulations. The request has been referred to the Director of the Office of Nuclear Reactor Regulation. As provided by 10 CFR 2.206, appropriate action will be taken on this petition within a reasonable time.
The petitioner met with the Petition Review Board on June 19, 2018, to discuss the petition; the transcript of that meeting is a supplement to the petition (ADAMS Accession No. ML18194A395). The petition and the results of the discussion at the June 19, 2018, meeting would be considered in establishing the schedule for the review of the petition.
For the Nuclear Regulatory Commission.
Nuclear Regulatory Commission.
License amendment application; opportunity to comment, request a hearing, and petition for leave to intervene.
The U.S. Nuclear Regulatory Commission (NRC) is considering issuance of amendments to Facility Operating License Nos. NPF-37 and NPF-66, issued to Exelon Generation Company (EGC), LLC, for operation of the Byron Station, Unit Nos. 1 and 2. The proposed amendment extends the Completion Time for Technical Specification 3.8.1, “AC Sources-Operating,” Required Action A.2, on a one-time, temporary basis based on a risk-informed approach.
Submit comments by October 1, 2018. Requests for a hearing or petition for leave to intervene must be filed by October 30, 2018.
You may submit comments by any of the following methods:
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For additional direction on obtaining information and submitting comments, see “Obtaining Information and Submitting Comments” in the
Joel S. Wiebe, Office of Nuclear Reactor Regulation, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001; telephone: 301-415-6606, email:
Please refer to Docket ID NRC-2018-0186 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:
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Please include Docket ID NRC-2018-0186 in 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 will post 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.
The NRC is considering issuance of amendments to Facility Operating License Nos. NPF-37 and NPF-66, issued to Exelon Generation Company (EGC), LLC, for operation of the Byron Station, Unit Nos. 1 and 2, located in Ogle County, Illinois.
The proposed amendment extends the Completion Time for Technical Specification 3.8.1, “AC Sources-Operating,” Required Action A.2, on a one-time, temporary basis based on a risk-informed approach.
Before any issuance of the proposed license amendment, the NRC will need to make the findings required by the Atomic Energy Act of 1954, as amended (the Act), and NRC's regulations.
The NRC has made a proposed determination that the license amendment request involves no significant hazards consideration. Under the NRC's regulations in section 50.92 of title 10 of the
1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?
The proposed change will provide a one-time, risk-informed revision to the CT [COMPLETION TIME] for the loss of one offsite source for Byron Station, Units 1 and 2 from 72 hours to 79 days. The proposed one-time extension of the CT for the loss of one offsite power circuit does not significantly increase the probability of an accident previously evaluated. The TSs [Technical Specifications] will continue to require equipment that will power safety related equipment necessary to perform any required safety function. The one-time extension of the CT to 79 days does not affect the design of the Unit 1 SATs [station auxiliary transformers], the interface of the SATs with other plant systems, the operating characteristic of the SATs, or the reliability of the SATs.
The consequence of a loss of offsite power (LOOP) event has been evaluated in the Byron Station Updated Final Safety Analysis Report (Reference 23 [in EGC's letter dated August 10, 2018]) and the Station Blackout evaluation. Increasing the CT for one offsite power source on a one-time basis from 72 hours to 79 days does not increase the consequences of a LOOP event nor change the evaluation of LOOP events. The plant will continue to respond to a LOOP in the same manner and with the same consequences as previously evaluated.
Therefore, the proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.
2. Does the proposed change create the possibility of a new or different kind of accident from any accident previously evaluated?
The proposed change does not result in a change in the manner in which the electrical distribution subsystems provide plant protection. The proposed change will only affect the time allowed to restore the operability of the offsite power source through a SAT. The proposed change to extend the TS CT does not affect the configuration, or operation of the plant. The proposed change to the CT will facilitate completion of repairs which will restore plant design to its as-built configuration, and will eliminate the necessity to shut down both Units if SAT 242-1 fails or requires maintenance that goes beyond the current TS CT of 72 hours. This change will support the restoration of the long-term reliability of the 345kV offsite circuit SAT which is common to both Byron Units.
There are no changes to the SATs or the supporting systems operating characteristics or conditions. The change to the CT does not change any existing accident scenarios, nor create any new or different accident scenarios. In addition, the change does not impose any new or different requirements or eliminate any existing requirements. The change does not alter any of the assumptions made in the safety analysis.
Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any previously evaluated.
3. Does the proposed change involve a significant reduction in a margin of safety?
The proposed change does not affect the acceptance criteria for any analyzed event nor is there a change to any safety limit. The proposed change does not alter the manner in which safety limits, limiting safety system settings, or limiting conditions for operation are determined. Neither the safety analyses nor the safety analysis acceptance criteria are affected by this change. The proposed change will not result in plant operation in a configuration outside the current design basis. The proposed activity only increases, for a one-time unanticipated occurrence, the period when Byron Station, Units 1 and 2 may operate with one offsite power source. The margin of safety is maintained by maintaining the ability to safely shut down the plant and remove residual heat.
Therefore, the proposed changes do not involve a significant reduction in a margin of safety.
Based on the above evaluation, EGC concludes that the proposed amendments do not involve a significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of no significant hazards consideration is justified.
The NRC staff has reviewed the licensee's analysis and, based on this review, it appears that the three standards of 10 CFR 50.92(c) are satisfied. Therefore, the NRC staff proposes to determine that the license amendment request involves a no significant hazards consideration.
The NRC is seeking public comments on this proposed determination that the license amendment request involves no significant hazards consideration. Any comments received within 30 days after the date of publication of this notice will be considered in making any final determination.
Normally, the Commission will not issue the amendment until the expiration of 60 days after the date of publication of this notice. The Commission may issue the license amendment before expiration of the 60-day notice period if the Commission concludes the amendment involves no
Within 60 days after the date of publication of this notice, any persons (petitioner) whose interest may be affected by this action may file a request for a hearing and petition for leave to intervene (petition) with respect to the action. Petitions shall be filed in accordance with the Commission's “Agency Rules of Practice and Procedure” in 10 CFR part 2. Interested persons should consult a current copy of 10 CFR 2.309. The NRC's regulations are accessible electronically from the NRC Library on the NRC's website at
As required by 10 CFR 2.309(d) the petition should specifically explain the reasons why intervention should be permitted with particular reference to the following general requirements for standing: (1) The name, address, and telephone number of the petitioner; (2) the nature of the petitioner's right under the Act to be made a party to the proceeding; (3) the nature and extent of the petitioner's property, financial, or other interest in the proceeding; and (4) the possible effect of any decision or order which may be entered in the proceeding on the petitioner's interest.
In accordance with 10 CFR 2.309(f), the petition must also set forth the specific contentions which the petitioner seeks to have litigated in the proceeding. Each contention must consist of a specific statement of the issue of law or fact to be raised or controverted. In addition, the petitioner must provide a brief explanation of the bases for the contention and a concise statement of the alleged facts or expert opinion which support the contention and on which the petitioner intends to rely in proving the contention at the hearing. The petitioner must also provide references to the specific sources and documents on which the petitioner intends to rely to support its position on the issue. The petition must include sufficient information to show that a genuine dispute exists with the applicant or licensee on a material issue of law or fact. Contentions must be limited to matters within the scope of the proceeding. The contention must be one which, if proven, would entitle the petitioner to relief. A petitioner who fails to satisfy the requirements at 10 CFR 2.309(f) with respect to at least one contention will not be permitted to participate as a party.
Those permitted to intervene become parties to the proceeding, subject to any limitations in the order granting leave to intervene. Parties have the opportunity to participate fully in the conduct of the hearing with respect to resolution of that party's admitted contentions, including the opportunity to present evidence, consistent with the NRC's regulations, policies, and procedures.
Petitions must be filed no later than 60 days from the date of publication of this notice. Petitions and motions for leave to file new or amended contentions that are filed after the deadline will not be entertained absent a determination by the presiding officer that the filing demonstrates good cause by satisfying the three factors in 10 CFR 2.309(c)(1)(i) through (iii). The petition must be filed in accordance with the filing instructions in the “Electronic Submissions (E-Filing)” section of this document.
If a hearing is requested, and the Commission has not made a final determination on the issue of no significant hazards consideration, the Commission will make a final determination on the issue of no significant hazards consideration. The final determination will serve to establish when the hearing is held. If the final determination is that the amendment request involves no significant hazards consideration, the Commission may issue the amendment and make it immediately effective, notwithstanding the request for a hearing. Any hearing would take place after issuance of the amendment. If the final determination is that the amendment request involves a significant hazards consideration, then any hearing held would take place before the issuance of the amendment unless the Commission finds an imminent danger to the health or safety of the public, in which case it will issue an appropriate order or rule under 10 CFR part 2.
A State, local governmental body, Federally-recognized Indian Tribe, or agency thereof, may submit a petition to the Commission to participate as a party under 10 CFR 2.309(h)(1). The petition should state the nature and extent of the petitioner's interest in the proceeding. The petition should be submitted to the Commission by October 30, 2018. The petition must be filed in accordance with the filing instructions in the “Electronic Submissions (E-Filing)” section of this document, and should meet the requirements for petitions set forth in this section, except that under 10 CFR 2.309(h)(2) a State, local governmental body, or Federally-recognized Indian Tribe, or agency thereof does not need to address the standing requirements in 10 CFR 2.309(d) if the facility is located within its boundaries. Alternatively, a State, local governmental body, Federally-recognized Indian Tribe, or agency thereof may participate as a non-party under 10 CFR 2.315(c).
If a hearing is granted, any person who is not a party to the proceeding and is not affiliated with or represented by a party may, at the discretion of the presiding officer, be permitted to make a limited appearance pursuant to the provisions of 10 CFR 2.315(a). A person making a limited appearance may make an oral or written statement of his or her position on the issues but may not otherwise participate in the proceeding. A limited appearance may be made at any session of the hearing or at any prehearing conference, subject to the limits and conditions as may be imposed by the presiding officer. Details regarding the opportunity to make a limited appearance will be provided by the presiding officer if such sessions are scheduled.
All documents filed in NRC adjudicatory proceedings, including a request for hearing and petition for leave to intervene (petition), any motion or other document filed in the proceeding prior to the submission of a request for hearing or petition to intervene, and documents filed by interested governmental entities that request to participate under 10 CFR 2.315(c), must be filed in accordance with the NRC's E-Filing rule (72 FR 49139; August 28, 2007, as amended at 77 FR 46562; August 3, 2012). The E-Filing process requires participants to
To comply with the procedural requirements of E-Filing, at least 10 days prior to the filing deadline, the participant should contact the Office of the Secretary by email at
Information about applying for a digital ID certificate is available on the NRC's public website at
A person filing electronically using the NRC's adjudicatory E-Filing system may seek assistance by contacting the NRC's Electronic Filing Help Desk through the “Contact Us” link located on the NRC's public website at
Participants who believe that they have a good cause for not submitting documents electronically must file an exemption request, in accordance with 10 CFR 2.302(g), with their initial paper filing stating why there is good cause for not filing electronically and requesting authorization to continue to submit documents in paper format. Such filings must be submitted by: (1) First class mail addressed to the Office of the Secretary of the Commission, U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, Attention: Rulemaking and Adjudications Staff; or (2) courier, express mail, or expedited delivery service to the Office of the Secretary, 11555 Rockville Pike, Rockville, Maryland 20852, Attention: Rulemaking and Adjudications Staff. Participants filing adjudicatory documents in this manner are responsible for serving the document on all other participants. Filing is considered complete by first-class mail as of the time of deposit in the mail, or by courier, express mail, or expedited delivery service upon depositing the document with the provider of the service. A presiding officer, having granted an exemption request from using E-Filing, may require a participant or party to use E-Filing if the presiding officer subsequently determines that the reason for granting the exemption from use of E-Filing no longer exists.
Documents submitted in adjudicatory proceedings will appear in the NRC's electronic hearing docket which is available to the public at
For further details with respect to this action, see the application for license amendment dated August 10, 2018 (ADAMS Accession No. ML18226A097).
For the Nuclear Regulatory Commission.
In notice document 2018-18758, appearing on pages 44070-44075 in the Issue of Wednesday, August 29, 2018, make the following correction:
On page 44070, in the second column, under the heading
83 FR 40095.
1 p.m., September 5, 2018.
OPIC's Sunshine Act notice of its Public Hearing in Conjunction with each Board meeting was published in the
Information on the hearing cancellation may be obtained from Catherine F.I. Andrade at (202) 336-8768, or via email at
Pension Benefit Guaranty Corporation.
Notice of intent to request extension of OMB approval.
The Pension Benefit Guaranty Corporation (PBGC) intends to request that the Office of Management and Budget extend its approval (with modifications), under the Paperwork Reduction Act of 1995, of the information collection related to PBGC's booklet, Qualified Domestic Relations Orders & PBGC. This notice informs the public of PBGC's intent and solicits public comment on the collection of information.
Comments must be submitted by October 30, 2018.
Comments may be submitted by any of the following methods:
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All submissions received must include the agency's name (Pension Benefit Guaranty Corporation, or PBGC) and refer to OMB Control No. 1212-0054. All comments received will be posted without change to PBGC's website,
Karen Levin (
A defined benefit pension plan that does not have enough money to pay benefits may be terminated if the employer responsible for the plan faces severe financial difficulty, such as bankruptcy, and is unable to maintain the plan. In such an event, PBGC becomes trustee of the plan and pays benefits, subject to legal limits, to plan participants and beneficiaries.
The benefits of a pension plan participant generally may not be assigned or alienated. Title I of ERISA provides an exception for domestic relations orders that relate to child support, alimony payments, or marital property rights of an alternate payee (a spouse, former spouse, child, or other dependent of a plan participant). The exception applies only if the domestic relations order meets specific legal requirements that make it a qualified domestic relations order (QDRO).
When PBGC is trustee of a plan, it reviews submitted domestic relations orders to determine whether the order is qualified before paying benefits to an alternate payee. The requirements for submitting a domestic relations order and the contents of such orders are established by statute. The models and the guidance provided by PBGC assist parties by making it easier for them to comply with ERISA's QDRO requirements in plans trusteed by PBGC; they do not create any additional requirements and result in a reduction of the statutory burden.
The Office of Management and Budget(OMB) has approved the collection of information in PBGC's booklet,
PBGC estimates that it will receive approximately 630 domestic relations orders each year from prospective alternate payees and participants. PBGC further estimates that the total average annual burden of this collection of information will be approximately 3,576 hours and $894,000.
PBGC is soliciting public comments to—
• Evaluate whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information will have practical utility;
• evaluate the accuracy of the agency's estimate of the burden of the proposed collection of information, including the validity of the methodologies and assumptions used;
• enhance the quality, utility, and clarity of the information to be collected; and
• minimize the burden of the collection of information on those who are to respond, including through the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology,
Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (“Act”),
The Exchange proposes to amend BOX Rule Rules 5050 (Series of Options Contracts Open for Trading) and 5070 (Long-term Options Contracts) to conform to the recently approved changes to the Options Listing Procedures Plan (“OLPP”).
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 these statements may be examined at the places specified in Item IV below. The self-regulatory organization has prepared summaries, set forth in Sections A, B, and C below, of the most significant aspects of such statements.
The purpose of this filing is to amend Rules 5050 (Series of Options Contracts Open for Trading) and 5070 (Long-term Options Contracts) to conform to the recently approved changes to the Options Listing Procedures Plan (“OLPP”).
The Exchange, which is one of the Participant Exchanges to the OLPP, currently has rules that are designed to incorporate the requirements of the OLPP.
First, the OLPP has been amended to change the earliest date on which new January LEAPS on equity options, options on Exchange Traded Funds (“ETF”), or options on Trust Issued Receipts (“TIR”) may be added to a single date (from three separate months). As noted in the OLPP Notice, in the past there were operational concerns related to adding new January LEAPs series for all options classes on which LEAPs were listed on a single trading day. And, the addition of new series in a pre-electronic trading environment was a manual process. To accommodate this, the addition of new January LEAPs series was spread across three months (September, October, and November). Today, however, these operational concerns related to January LEAPs have been alleviated as new series can be added in bulk electronically. The Plan Participants, including the Exchange, believe that moving the addition of new January LEAPs series to no earlier than the Monday prior to the September expiration would reduce marketplace confusion about available January LEAPs series. Where previously January LEAPs series for options classes on the February or March expiration cycles would not have been available as early as January LEAPs series for options classes on the January expiration cycle, under the proposed change, all January LEAPs series will be available concurrently.
Accordingly, to conform to this change, the Exchange proposes to modify Rule 5070(c) to reflect that new January LEAPS series on equity options classes, options on ETFs, or options on TIRs, may not be added on a currently listed and traded option class earlier than the Monday prior to the September expiration (which is 28 months before the expiration).
Second, the OLPP has been amended to allow equity, ETF, and TIR option series to be added based on trading after regular trading hours (
The Exchange proposes to modify Rule 5070(b) to delete now obsolete operational language, which dates back to when LEAPs were first adopted. The language in question provides that:
After a new long-term options contract series is listed, such series will be opened for trading either when there is buying or selling interest, or forty (40) minutes prior to the close, whichever occurs first. No quotations will be posted for such options series until they are opened for trading.
The Exchange proposes to delete this language because when this language was adopted LEAPs were not opened for trading until late in the trading day unless there was buying or selling interest. Today, however, technological improvements allow the Exchange to open all LEAP series at the same time as all other series in an option class.
The Exchange believes that the proposal is consistent with the requirements of Section 6(b) of the Securities Exchange Act of 1934 (the “Act”),
In particular, the proposed rule change, which conforms to the recently adopted provisions of the OLPP, as amended, allows the Exchange to continue to list extended far term option series that have been viewed as beneficial to traders, investors and public customers. Accordingly, the Exchange believes that the proposal is consistent with the Act because it will allow the Exchange to list all January, 2021 expiration series on the Monday prior to the September, 2018 expiration. Moreover, this change would simplify the process for adding new January LEAP options series and reduce potential for investor confusion because all new January LEAP options would be made available beginning at the same time, consistent with the amended OLPP. The Exchange notes that this proposal does not propose any new provisions that have not already been approved by the Commission in the amended OLPP, but instead maintains series listing rules that conform to the amended OLPP.
The proposal to permit series to be added based on after-market trading is designed to promote just and equitable principles of trade, to foster cooperation and coordination with persons engaged in facilitating transactions in securities, and to remove impediments to and perfect the mechanisms of a free and open market and a national market system, by allowing the Exchange to make series available for trading with reduced operational difficulties. The Exchange notes that this proposed change, which is consistent with the amended OLPP should provide market participants with earlier notice regarding what options series will be available for trading the following day, and should help to enhance investors' ability to plan their options trading.
The Exchange also believes that the proposed technical changes, including deleting obsolete language and reorganizing and consolidating the rule, promote just and equitable principles of trade, foster cooperation and coordination with persons engaged in facilitating transactions in securities, and remove impediments to and perfect the mechanism of a free and open market and a national market system.
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. Specifically, the Exchange believes that by conforming Exchange rules to the amended OLPP, the Exchange would promote regulatory clarity and consistency, thereby reducing burdens on the marketplace and facilitating investor protection. The Exchange believes that adopting rules, which it anticipates will likewise be adopted by Participant Exchanges, would allow for continued competition between Exchange market participants trading similar products as their counterparts on other exchanges, while at the same time allowing the Exchange to continue to compete for order flow with other exchanges in option issues.
The Exchange has neither solicited nor received comments on the proposed rule change.
The Exchange has filed the proposed rule change pursuant to Section 19(b)(3)(A)(iii) of the Act
A proposed rule change filed under Rule 19b-4(f)(6)
At any time within 60 days of the filing of such 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
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) of the Securities Exchange Act of 1934 (the “Act”),
The Exchange is proposing to amend Rules 19.8 and 29.11.
The text of the proposed rule change is available at the Exchange's website 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 parts of such statements.
The purpose of this proposed rule change is to amend Rules 19.8 and 29.11 to delete now obsolete operational language, which dates back to when long-term options contracts were first adopted. This language provides that when a new equity or index long-term options contract series, as applicable, is listed, such series will be opened for trading either when there is buying or selling interest, or 40 minutes prior to the close, whichever occurs first. No quotations will be posted for such option series until they are opened for trading. The Exchange proposes to delete this language because when this language was adopted, long-term options contracts were not opened for trading until late in the trading day unless there was buying or selling interest. Today, however, technological improvements
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.
In particular, the Exchange believes the proposed rule change will remove impediments to and perfect the mechanism of a free and open market and a national market system, because deleting obsolete rules will more clearly identify for market participants currently applicable rules.
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. The proposed rule change deletes an obsolete operation rule, which no longer applies, and thus will have no impact on trading. Therefore, the proposed rule change has no impact on competition. The proposed rule change eliminates confusion with respect to rules applicable to current trading on the Exchange. Additionally, two other options exchanges recently deleted the same provision.
The Exchange neither solicited nor received comments on the proposed rule change.
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 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 under Rule 19b-4(f)(6)
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.
Interested persons are invited to submit written data, views and arguments concerning the foregoing, including whether the proposal 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) of the Securities Exchange Act of 1934 (the “Act”),
The Exchange is proposing to amend Rules 19.8 and 29.11.
The text of the proposed rule change is available at the Exchange's website 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 parts of such statements.
The purpose of this proposed rule change is to amend Rules 19.8 and 29.11 to delete now obsolete operational language, which dates back to when long-term options contracts were first adopted. This language provides that when a new equity or index long-term options contract series, as applicable, is listed, such series will be opened for trading either when there is buying or selling interest, or 40 minutes prior to the close, whichever occurs first. No quotations will be posted for such option series until they are opened for trading. The Exchange proposes to delete this language because when this language was adopted, long-term options contracts were not opened for trading until late in the trading day unless there was buying or selling interest. Today, however, technological improvements
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.
In particular, the Exchange believes the proposed rule change will remove impediments to and perfect the mechanism of a free and open market and a national market system, because deleting obsolete rules will more clearly identify for market participants currently applicable rules.
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. The proposed rule change deletes an obsolete operation rule, which no longer applies, and thus will have no impact on trading. Therefore, the proposed rule change has no impact on competition. The proposed rule change eliminates confusion with respect to rules applicable to current trading on the Exchange. Additionally, two other options exchanges recently deleted the same provision.
The Exchange neither solicited nor received comments on the proposed rule change.
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 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 under Rule 19b-4(f)(6)
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.
Interested persons are invited to submit written data, views and arguments concerning the foregoing, including whether the proposal 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.
Social Security Administration (SSA).
Notice of a new matching program.
In accordance with the provisions of the Privacy Act, as amended, this notice announces a new matching program with the Bureau of the Fiscal Service, Department of the Treasury (Fiscal Service).
This agreement between SSA and Fiscal Service sets forth the terms, conditions, and safeguards under which Fiscal Service will disclose ownership of Savings Securities data to SSA. This disclosure will provide SSA with information necessary to verify an individual's self-certification of his or her financial status to determine eligibility for low-income subsidy assistance (Extra Help) in the Medicare Part D prescription drug benefit program established under the Medicare Prescription Drug, Improvement, and Modernization Act of 2003.
The deadline to submit comments on the proposed matching program is 30 days from the date of publication of this notice in the
Interested parties may comment on this notice by either telefaxing to (410) 966-0869, writing to Mary Ann Zimmerman, Acting Executive Director, Office of Privacy and Disclosure, Office of the General Counsel, Social Security Administration, G-401 WHR, 6401 Security Boulevard, Baltimore, MD 21235-6401, or emailing
Interested parties may submit general questions about the matching program to Mary Ann Zimmerman, Acting Executive Director, Office of Privacy and Disclosure, Office of the General Counsel, by any of the means shown above.
None.
SSA will disclose to Fiscal Service a finder file with the SSN for each individual for whom it requests Savings Securities registration information. Fiscal Service bases the query on the SSN associated with the account and reports any subsequent account holdings. When a match occurs on an SSN, Fiscal Service will disclose the following to SSA: The purchase amount; the account number and confirmation number; the series; the issue date of the security; the current redemption value; and the return date of the finder file.
Fiscal Service will match the SSNs from SSA's finder file with the SSNs in Fiscal Service Savings Securities Registration Systems, which reside in the systems of records Treasury/BPD.002, “United States Savings-Type Securities Treasury/BPD” and Treasury/BPD.008, “Retail Treasury Securities Access Application-Treasury/BPD” fully published at 73 FR 42904 on July 23, 2008 and amended at 76 FR 51128 on August 17, 2011.
Department of State.
Notice of extension of passport travel restriction.
On September 1, 2017, all United States passports were declared invalid for travel to, in, or through the Democratic People's Republic of Korea (DPRK) unless specially validated for such travel. If not renewed, the restriction is set to expire on August 31, 2018. This notice extends the restriction until August 31, 2019 unless extended or sooner revoked by the Secretary of State.
The extension of the travel restriction is in effect on September 1, 2018.
Anita Mody, Bureau of Consular Affairs, Passport Services, Office of Legal Affairs, 202-485-6500.
On September 1, 2017, pursuant to the authority of 22 U.S.C. 211a and Executive Order 11295 (31 FR 10603), and in accordance with 22 CFR 51.63(a)(2), all United States passports were declared invalid for travel to, in, or through the Democratic People's Republic of Korea (DPRK) unless specially validated for such travel. If not renewed, the restriction is set to expire on August 31, 2018.
The Department of State has determined that there continues to be serious risk to United States nationals of arrest and long-term detention representing imminent danger to the physical safety of United States nationals traveling to and within the DPRK, within the meaning of 22 CFR 51.63(a)(3). Accordingly, all United States passports shall remain invalid for travel to, in, or through the DPRK unless specially validated for such travel under the authority of the Secretary of State. This extension to the restriction of travel to the DPRK shall be effective on September l, 2018, and shall expire August 31, 2019 unless extended or sooner revoked by the Secretary of State.
Clackamas Valley Railway, LLC (CVR), a noncarrier,
This transaction is related to a concurrently filed verified notice of exemption in
CVR states that the Line is currently operated by UP as excepted track under 49 U.S.C. 10906. However, because it will operate the Line as its entire line of railroad, CVR asserts that it will become a rail carrier upon consummation of the proposed transaction.
CVR certifies that its projected annual revenues from this transaction will not result in the creation of a Class I or Class II rail carrier and will not exceed $5 million. As required under 49 CFR 1150.33(h)(1), CVR has disclosed in its verified notice that the lease agreement contains an interchange commitment that prohibits CVR from entering into any other agreement for the movement of CVR traffic without the prior consent of UP. CVR has provided additional information regarding the interchange commitment as required by 49 CFR 1150.33(h).
Although CVR states in its verified notice that the transaction is proposed to be consummated on or about August
If the verified notice contains false or misleading information, the exemption is void ab initio. Petitions to revoke the exemption under 49 U.S.C. 10502(d) may be filed at any time. The filing of a petition to revoke will not automatically stay the effectiveness of the exemption. Petitions to stay must be filed no later than September 7, 2018 (at least seven days before the exemption becomes effective).
An original and 10 copies of all pleadings, referring to Docket No. FD 36211, must be filed with the Surface Transportation Board, 395 E Street SW, Washington, DC 20423-0001. In addition, a copy of each pleading must be served on CVR's representative, Bradon J. Smith, Fletcher & Sippel LLC, 29 North Wacker Drive, Suite 800, Chicago, IL 60606-3208.
According to CVR, this action is categorically excluded from environmental review under 49 CFR 1105.6(c) and from historic reporting under 49 CFR 1105.8(b).
Board decisions and notices are available on our website at
By the Board, Scott M. Zimmerman, Acting Director, Office of Proceedings.
Progressive Rail Incorporated (PGR), a Class III rail carrier, has filed a verified notice of exemption under 49 CFR 1180.2(d)(2) to continue in control of Clackamas Valley Railway, LLC (CVR), upon CVR's becoming a Class III rail carrier.
This transaction is related to a concurrently filed verified notice of exemption in
The earliest this transaction may be consummated is September 15, 2018 (30 days after the verified notice was filed).
PGR will continue in control of CVR upon CVR's becoming a Class III rail carrier. According to PGR, it owns or operates rail lines in Minnesota, Wisconsin, and Illinois. PGR states that it controls six other Class III railroads that operate in Minnesota, Missouri, Iowa, North Carolina, Illinois, and California,
PGR states that: (1) The Line to be operated by CVR does not connect with any other railroads in the PGR corporate family; (2) the continuance in control is not part of a series of anticipated transactions that would connect the Line with any other railroad in the PGR corporate family; and (3) the transaction does not involve a Class I rail carrier. Therefore, the proposed transaction is exempt from the prior approval requirements of 49 U.S.C. 11323.
Under 49 U.S.C. 10502(g), the Board may not use its exemption authority to relieve a rail carrier of its statutory obligation to protect the interests of its employees. Section 11326(c), however, does not provide for labor protection for transactions under §§ 11324 and 11325 that involve only Class III rail carriers. Accordingly, the Board may not impose labor protective conditions here, because all the carriers involved are Class III carriers.
If the verified notice contains false or misleading information, the exemption is void ab initio. Petitions to revoke the exemption under 49 U.S.C. 10502(d) may be filed at any time. The filing of a petition to revoke will not automatically stay the effectiveness of the exemption. Petitions to stay must be filed no later than September 7, 2018 (at least seven days before the exemption becomes effective).
An original and 10 copies of all pleadings, referring to Docket No. FD 36212, must be filed with the Surface Transportation Board, 395 E Street SW, Washington, DC 20423-0001. In addition, a copy of each pleading must be served on PGR's representative, Bradon J. Smith, Fletcher & Sippel LLC, 29 North Wacker Drive, Suite 800, Chicago, IL 60606-3208.
According to PGR, this action is categorically excluded from environmental review under 49 CFR 1105.6(c) and from historic reporting under 49 CFR 1105.8(b).
Board decisions and notices are available on our website at
By the Board, Scott M. Zimmerman, Acting Director, Office of Proceedings.
Federal Aviation Administration (FAA), DOT.
Notice and request for comments.
In accordance with the Paperwork Reduction Act of 1995, FAA invites public comments about our intention to request the Office of Management and Budget (OMB) approval to renew an information collection. The revision of this collection involves the amendment of regulations, which allows a certificate holder's pilots to log second-in-command (SIC) time in operations that does not otherwise require a SIC. This revision also removes the burden for initial certification as that is already counted under ICR 2120-0593.
Written comments should be submitted by October 1, 2018.
Interested persons are invited to 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 attention of the Desk Officer, Department of Transportation/FAA, and sent via electronic mail to
Barbara Hall at (940) 594-5913, or by email at:
The FAA is also changing certain logging requirements to enable the logging of SIC time obtained under a SIC PDP. Those changes are reflected in a revision to information collection 2120-0021.
The FAA estimates that approximately 20 operators would be required to submit a newly developed SIC Professional Development Training Program for approval in the first year that the program is available. The FAA estimates that 50 operators will request an amendment to their existing PIC/SIC training program. This time burden is reflected in § 135.325, Training program and revision.
The FAA estimates that 20 operators will take approximately 40 hours each to develop and submit an acceptable new SIC training program. This program change will result in a burden increase of 800 hours in the first year of information collection only.
The FAA estimates that 50 operators will take approximately 20 hours each to revise and submit an acceptable SIC training program. This program change will result in a burden increase of 1,000 hours.
The new or revised SIC training program will result in a burden of 1,800 total hours in the first year of information collection.
In addition, the FAA has revised the burden in section 135.325 to remove the calculation of the burden for new applicants (for initial approval of training programs); this burden should not be reflected in this collection as it is already addressed in a previously approved collection (2120-0593 Certification: Air Carriers and Commercial Operators—FAR Part 119). This change is necessary to avoid double-counting the burden.
Federal Aviation Administration (FAA), DOT.
Notice and request for comments.
In accordance with the Paperwork Reduction Act of 1995, FAA invites public comments about our intention to request the Office of Management and Budget (OMB) approval to renew an information collection. The revision of this collection involves the logging of training time in aviation training devices under the provisions of regulations specified in the background of this document, and the logging of flight time as a second in command (SIC) under the provisions of regulations specified in the background of this document.
Written comments should be submitted by October 1, 2018.
Interested persons are invited to 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 attention of the Desk Officer, Department of Transportation/FAA, and sent via electronic mail to
Barbara Hall at (940) 594-5913, or by email at:
The FAA estimates that, of the 102,811 active pilots with an instrument rating, that approximately 50% are maintaining currency. It is likely that only 15% of those pilots (approximately 15,422 pilots) are using an aviation training device exclusively to maintain their instrument currency. For those pilots, this change will reduce the recordkeeping requirements of logging time from 6 times a year to two times a year, when logging instrument currency exclusively in an aviation training device. The FAA estimates this burden reduction to be 6168.8 hours annually.
Additionally, the final rule amends § 135.99 by adding paragraph (c) to allow a certificate holder to receive approval of a second in command (SIC) professional development program (SIC PDP) via operations specifications (Ops Specs) to allow the certificate holder's pilots to log SIC time in operations conducted under part 135 in an airplane or operation that does not otherwise require a SIC. Specifically, with this final rule, § 61.159(c) allows pilots to log SIC time in part 135 operations in a single engine turbine-powered airplane or a multi-engine airplane that otherwise does not require an SIC. This will require the pilot to obtain a logbook endorsement from the pilot in command for each individual flight to log this time as SIC. The FAA estimates that of the 76,957 Commercial Pilots with airplane and instrument privileges that approximately 10% (7,696) may actively pursue a SIC position with a Part 135 operator that is approved for logging SIC time as described for this provision. However, because of the limited number of operators (approximately 457 operators as of September 28, 2017) that would qualify or actually pursue this authorization, the FAA estimates that only 15% (1,154 pilots) might actually become qualified annually to log SIC time under this provision. This additional record keeping requirement will be reflected in Section 61.159, Aeronautical experience. The FAA estimates this SIC training program burden increase is 1,154 hours annually.
Federal Highway Administration (FHWA), DOT.
Notice of Limitation on Claims for Judicial Review of Actions by FHWA and Other Federal Agencies.
This notice announces actions taken by FHWA and other Federal agencies that are final within the meaning of title 23 of the United States Code. The actions relate to the replacement of the temporary Wainiha Bridges along Kūhiō Highway (State Route 560) at approximate Mileposts 6.4 and 6.7, which is located in the Halele`a District on the island of Kaua`i, State of Hawai`i. Those actions grant licenses, permits, and approvals for the project.
By this notice, FHWA is advising the public of final agency actions subject to 23 U.S.C. 139(l)(1). A claim seeking judicial review of the Federal agency actions on the highway project will be barred unless the claim is filed on or before January 28, 2019. If the Federal law that authorizes judicial review of a claim provides a time period
Thomas Parker, Project Manager, Federal Highway Administration, Central Federal Lands Highway Division, 12300 W Dakota Avenue, Suite 380, Lakewood, Colorado 80228, Telephone (720) 963-3688, Email
Notice is hereby given that FHWA and other Federal agencies have taken final agency actions by issuing licenses, permits, and approvals for the following highway project in the State of Hawai`i: Project to Replace Temporary Wainiha Bridges (Replacement of the Temporary Wainiha Bridges and Rehabilitation of Kaua`i Belt Road).
This notice applies to all Federal agency decisions, actions, approvals, licenses and permits on the project as of the issuance date of this notice, including but not limited to those arising under the following laws, as amended:
1.
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4.
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23 U.S.C. 139(1)(1).
Federal Railroad Administration (FRA), Department of Transportation (DOT).
Notice of Information Collection; request for comment.
Under the Paperwork Reduction Act of 1995 (PRA), this notice announces that FRA is forwarding the Information Collection Request (ICR) abstracted below to the Office of Management and Budget (OMB) for review and comment. The ICR describes the information collections and their expected burden. On July 2, 2018, FRA published a notice providing a 60-day period for public comment on the ICR.
Interested persons are invited to submit comments on or before October 1, 2018.
Submit written comments on the ICR to the Office of Information and Regulatory Affairs, Office of Management and Budget, 725 17th Street NW, Washington, DC 20503, Attention: FRA Desk Officer. Comments may also be sent via email to OMB at the following address:
Mr. Michael Jones, Information Collection Clearance Officer, Office of Railroad Policy & Development, Human Factors Division, RPD-34, Federal Railroad Administration, 1200 New Jersey Avenue SE, Room W38-119, Washington, DC 20590 (telephone: (202) 493-6106); or Ms. Kim Toone, Information Collection Clearance Officer, Office of Administration, Office of Information Technology, RAD-20, Federal Railroad Administration, 1200 New Jersey Avenue SE, Room W34-212, Washington, DC 20590 (telephone: (202) 493-6132).
The PRA, 44 U.S.C. 3501-3520, and its implementing regulations, 5 CFR part 1320, require Federal agencies to issue two notices seeking public comment on information collection activities before OMB may approve paperwork packages.
Before OMB decides whether to approve these proposed collections of information, it must provide 30 days for public comment. Federal law requires OMB to approve or disapprove paperwork packages between 30 and 60 days after the 30-day notice is published. 44 U.S.C. 3507(b)-(c); 5 CFR 1320.10(b);
The summary below describes the ICR that FRA will submit for OMB clearance as the PRA requires:
FRA administers award agreements for both construction and non-construction projects that will result in benefits or other tangible improvements in rail corridors, service, safety, and technology. These projects include completion of preliminary engineering, environmental, research and development, final design, and construction.
FRA requires systematic and uniform collection and submission of information, as approved by OMB, to ensure accountability of Federal assistance provided by FRA. Through this information collection, FRA will measure Federal award recipients' performance and results, including expenditures in support of agreed-upon activities and allowable costs outlined in a FRA Notice of Grant Award (NGA). This information collection includes OMB-required reports and documentation, as well as additional forms and submissions to compile evidence relevant to addressing FRA's important policy challenges, promoting cost-effectiveness in FRA programs, and providing effective oversight of programmatic and financial performance. FRA issues and manages awards in compliance with 2 CFR part 200, Uniform Administrative Requirements, Cost Principles, and Audit Requirements for Federal Awards. The forms for which FRA is seeking renewal of its current approval in this information collection are listed below. All non-research awards are subject to the application, reporting, closeout, and other processes described in this justification.
Under 44 U.S.C. 3507(a) and 5 CFR 1320.5(b) and 1320.8(b)(3)(vi), FRA informs all interested parties that it may not conduct or sponsor, and a respondent is not required to respond to a collection of information unless it displays a currently valid OMB control number.
44 U.S.C. 3501-3520.
Office of the Secretary (OST), DOT.
Notice and request for comments.
In compliance with the Paperwork Reduction Act of 1995, the U.S. Department of Transportation invites the general public, industry and other governmental parties to comment on the information collection request (ICR) OMB No. 2105-0009 Committee Candidate Biographical Information Request Form. The information collection request previously approved by the Office of Management and Budget (OMB) expired on May 31, 2012. The collection is needed to facilitate background investigations of individuals seeking or currently appointed to a Department committee. A
Written comments should be submitted by October 1, 2018.
David Freeman, Program Analyst, Executive Secretariat, U.S. Department of Transportation, 1200 New Jersey Avenue SE, Washington, DC 20590-0001 or telephone: (202) 366-2918.
Refer to OMB Control No. 2105-0009.
Written comments should be submitted to the attention of the
The Paperwork Reduction Act of 1995; 44 U.S.C. Chapter 35, as mended; and 49 CFR 1:48.
Issued in Washington, DC.
Veterans Benefits Administration, Department of Veterans Affairs
Notice.
In compliance with the Paperwork Reduction Act (PRA) of 1995, this notice announces that the Veterans Benefits Administration (VBA), Department of Veterans Affairs, will submit the collection of information abstracted below to the Office of Management and Budget (OMB) for review and comment. The PRA submission describes the nature of the information collection and its expected cost and burden; it includes the actual data collection instrument.
Comments must be submitted on or before October 1, 2018.
Submit written comments on the collection of information through
Cynthia Harvey-Pryor, Office of Quality, Privacy and Risk (OQPR), Department of Veterans Affairs, 810 Vermont Avenue NW, Washington, DC 20420, (202) 461-5870 or email
Please refer to “OMB Control No. 2900-0682” in any correspondence.
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
By direction of the Secretary.
Veterans Benefits Administration, Department of Veterans Affairs.
Notice.
In compliance with the Paperwork Reduction Act (PRA) of 1995, this notice announces that the Veterans Benefits Administration, Department of Veterans Affairs, will submit the collection of information abstracted below to the Office of Management and Budget (OMB) for review and comment. The PRA submission describes the nature of the information collection and its expected cost and burden and it includes the actual data collection instrument.
Comments must be submitted on or before October 1, 2018.
Submit written comments on the collection of information through
Cynthia Harvey-Pryor, Enterprise Records Service (005R1B), Department of Veterans Affairs, 811 Vermont Avenue NW, Washington, DC 20420, (202) 461-5870 or email
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
By direction of the Secretary:
Veterans Health Administration, Department of Veterans Affairs.
Notice.
In compliance with the Paperwork Reduction Act (PRA) of 1995, this notice announces that the Veterans Health Administration, Department of Veterans Affairs, will submit the collection of information abstracted below to the Office of Management and Budget (OMB) for review and comment. The PRA submission describes the nature of the information collection and its expected cost and burden and it includes the actual data collection instrument.
Comments must be submitted on or before October 1, 2018.
Submit written comments on the collection of information through
Cynthia Harvey-Pryor, Enterprise Records Service (005R1B), Department of Veterans Affairs, 810 Vermont Avenue NW, Washington, DC 20420, (202) 461-5870 or email
a. Veterans Outcome Assessment—Baseline.
b. Veterans Outcome Assessment—Follow Up.
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
By direction of the Secretary.
Veterans Benefits Administration, Department of Veterans Affairs.
Notice.
In compliance with the Paperwork Reduction Act (PRA) of 1995, this notice announces that the Veterans Benefits Administration (VBA), Department of Veterans Affairs, will submit the collection of information abstracted below to the Office of Management and Budget (OMB) for review and comment. The PRA submission describes the nature of the information collection and its expected cost and burden; it includes the actual data collection instrument.
Comments must be submitted on or before October 1, 2018.
Submit written comments on the collection of information through
Cynthia Harvey-Pryor, Office of Quality, Privacy and Risk (OQPR), Department of Veterans Affairs, 810 Vermont Avenue NW, Washington, DC 20420, (202) 461-5870 or email
Please refer to “OMB Control No. 2900-0695” in any correspondence.
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
By direction of the Secretary.
Veterans Health Administration, Department of Veterans Affairs.
Notice.
Veterans Health Administration, 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
Submit written comments on the collection of information through Federal Docket Management System (FDMS) at
Brian McCarthy at (202) 615-9241.
Under the PRA of 1995, 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, VHA invites comments on: (1) Whether the proposed collection of information is necessary for the proper performance of VHA's functions, including whether the information will have practical utility; (2) the accuracy of VHA'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.
Securities and Exchange Commission.
Final rule.
The Securities and Exchange Commission (“Commission” or “SEC”) is adopting amendments to the Municipal Securities Disclosure Rule under the Securities Exchange Act of 1934 (“Exchange Act”). The amendments add transparency to the municipal securities market by increasing the amount of information that is publicly disclosed about material financial obligations incurred by issuers and obligated persons. Specifically, the amendments revise the list of event notices that a broker, dealer, or municipal securities dealer (each a “dealer,” and collectively, “dealers”) acting as an underwriter (“Participating Underwriter”) in a primary offering of municipal securities with an aggregate principal amount of $1,000,000 or more (subject to certain exemptions set forth in the Rule) (an “Offering”) must reasonably determine that an issuer or an obligated person has undertaken, in a written agreement or contract for the benefit of holders of the municipal securities, to provide to the Municipal Securities Rulemaking Board (“MSRB”).
Rebecca Olsen, Acting Director; Ahmed Abonamah, Senior Counsel to the Director; Mary Simpkins, Senior Special Counsel; Hillary Phelps, Senior Counsel; or William Miller, Attorney-Adviser; Office of Municipal Securities, Securities and Exchange Commission, 100 F Street NE, Washington, DC 20549-6628 or at (202) 551-5680.
The Commission is adopting amendments to 17 CFR 240.15c2-12 (“Rule 15c2-12” or “Rule”) under the Securities Exchange Act of 1934. The amendments (a) amend the list of events for which notice is to be provided to include (i) incurrence of a financial obligation of the obligated person, if material, or agreement to covenants, events of default, remedies, priority rights, or other similar terms of a financial obligation of the obligated person, any of which affect security holders, if material; and (ii) default, event of acceleration, termination event, modification of terms, or other similar events under the terms of a financial obligation of the obligated person, any of which reflect financial difficulties; and (b) define the term “financial obligation” to mean a (i) debt obligation; (ii) derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation; or (iii) a guarantee of (i) or (ii). The term financial obligation shall not include municipal securities as to which a final official statement has been provided to the Municipal Securities Rulemaking Board consistent with this rule.
In March 2017, the Commission published for comment proposed amendments to Exchange Act Rule 15c2-12
In addition, the Commission proposed a definition of the term “financial obligation.” As proposed, the term financial obligation would have meant a (i) debt obligation; (ii) lease; (iii) guarantee; (iv) derivative instrument; and (v) monetary obligation resulting from a judicial, administrative, or arbitration proceeding. The term financial obligation would not have included municipal securities as to which a final official statement has been provided to the Municipal Securities Rulemaking Board consistent with this rule.
The Commission also proposed a technical amendment to paragraph (b)(5)(i)(C)(
A wide range of commenters sent comment letters
The Commission has carefully considered all of the comments and, as discussed below, is adopting the amendments substantially as proposed, with some modifications to address issues raised by commenters.
The amendments address the need for timely disclosure of important information related to an issuer's or obligated person's financial obligations. The Commission believes that the amendments will facilitate investors' and other market participants' access to important information in a timely manner, enhance transparency in the municipal securities market, and improve investor protection. For the reasons discussed in this Adopting Release, the Commission believes that the amendments are consistent with the Commission's mandate to, among other things, adopt rules reasonably designed to prevent fraudulent, deceptive, or manipulative acts or practices in the municipal securities market.
Rule 15c2-12 is designed to address fraud by enhancing disclosure in the municipal securities market by establishing standards for obtaining, reviewing, and disseminating information about municipal securities by their underwriters.
In July 2012, the Commission issued a Report on the Municipal Securities Market, following a broad review of the municipal securities market that included a series of public field hearings and numerous meetings with market participants.
Currently, the municipal securities market has over $3.844 trillion in principal outstanding.
As the Commission discussed in the Proposing Release, in recent years issuers and obligated persons have increasingly used direct purchases of municipal securities
According to information received by Commission staff from MSRB staff, the MSRB received 648 filings during calendar year 2017 under the “Bank Loan/Alternative Financing Filing” category.
As discussed in detail below, the Commission is adopting, substantially as proposed, amendments to Rule 15c2-12. The amendments add the following events, as proposed, as paragraphs (b)(5)(i)(C)(
In addition, the Commission is adding, substantially as proposed, to paragraph (f) of the Rule, the following definition: The term financial obligation means a (i) debt obligation; (ii) derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation; or (iii) guarantee of (i) or (ii). The term financial obligation shall not include municipal securities as to which a final official statement has been provided to the Municipal Securities Rulemaking Board consistent with this rule.
The Commission is also adopting, as proposed, a technical amendment to paragraph (b)(5)(i)(C)(
In keeping with the objectives set forth in the Exchange Act, including Section 15(c)(2),
Commenters were generally supportive of increased transparency in the municipal securities market.
The Commission acknowledges the efforts of many issuers and obligated persons to be transparent. However, as stated in the Proposing Release, investors and other market participants may not learn that the issuer or obligated person has incurred a financial obligation if the issuer or obligated person does not provide annual financial information or audited financial statements to EMMA or does not subsequently issue debt in a primary offering subject to Rule 15c2-12 that results in the provision of a final official statement to EMMA.
Additionally, the Commission understands that to the extent information about financial obligations is disclosed and accessible to investors and other market participants, such
Additionally, the Commission recognizes that the Tax Cuts and Jobs Act of 2017 may impact the municipal debt market, including, but not limited to the use of direct placements. The amendments are intended to address the need for timely disclosure of important information related to an issuer's or obligated person's financial obligations and cover a variety of obligations incurred by issuers and obligated persons, including but not limited to direct placements.
The Commission also recognizes the efforts of the MSRB, the Financial Industry Regulatory Authority (“FINRA”), academics, and industry groups to promote voluntary disclosure of financial obligations. However, as described in the Proposing Release, despite these ongoing efforts, few issuers or obligated persons have made voluntary disclosures of financial obligations, including direct placements, to the MSRB.
The Commission is adopting as proposed new paragraph (b)(5)(i)(C)(
Commenters raised a number of concerns related to the materiality qualifier contained in proposed new paragraph (b)(5)(i)(C)(
Several commenters addressed the Commission's use of a materiality standard in proposed paragraph (b)(5)(i)(C)(
Materiality is a core principle that guides the Commission's approach to securities regulation, and a materiality qualifier has appeared in Rule 15c2-12 since the Rule was amended in 1994.
The Commission continues to believe that including a materiality qualifier in the amendments is appropriate as it provides a framework for issuers and obligated persons to assess their disclosure obligations in the context of the specific facts and circumstances. As described in the Proposing Release, the Commission believes that not every incurrence of a financial obligation or agreement to terms is material.
Separately, some commenters suggested that the amendments include a mechanical test for materiality. In 1994, the Commission proposed amendments to Rule 15c2-12 that would have used a mechanical test to identify any “significant obligor” with respect to an issue of municipal securities and require that both the final official statement and the annual financial information provided on an ongoing basis pursuant to the continuing disclosure agreement include disclosure with respect to any significant obligor.
Numerous commenters asked the Commission to provide guidance on how to determine the materiality of a financial obligation, stating that without such guidance, issuers, obligated persons, and dealers would not interpret materiality uniformly.
The Commission believes that the type of analysis undertaken in connection with the MCDC Initiative
The Commission believes that the determination by an issuer or obligated person of whether to submit an event notice under paragraph (b)(5)(i)(C)(
Since 2010, paragraphs (b)(5)(i)(C)(
Furthermore, this type of analysis is frequently conducted under the securities laws, whereby materiality is determined by reference to whether there is a substantial likelihood that a reasonable security holder would consider the information important in deciding whether to buy or sell a security.
Due to the flexible facts-and-circumstances approach to assessing materiality, the Commission acknowledges, as raised by commenters, that in the course of providing disclosures to the market about their financial obligations, some issuers and obligated persons may have differing opinions with respect to whether a piece of information would be considered important to a reasonable investor when making an investment decision. Regardless of these potential differences of opinion, the Commission does not believe it is necessary to provide additional guidance at this time. Issuers and obligated persons have the benefit of experience with making materiality determinations under the federal securities laws generally and the Rule specifically. Furthermore, even absent uniformity, the amendments, as discussed throughout this Release, will result in increased timely disclosure in the municipal securities market of important information regarding the financial obligations of issuers and obligated persons. Additionally, the changes made to the proposed definition of financial obligation should also alleviate commenter concerns about assessing the materiality of each financial obligation incurred by issuers and obligated persons. Forms and guidance that the industry may develop in this area could also assist issuers and obligated persons in evaluating which financial obligations should be disclosed pursuant to their continuing disclosure agreements.
Many commenters stated that materiality determinations would pose
The Commission acknowledges that there will be costs incurred by issuers, obligated persons, and dealers when evaluating whether a financial obligation is material. However, as discussed in Section III.A.2 herein, the Commission is adopting a narrower definition of “financial obligation” than proposed, which will reduce the burden on issuers, obligated persons, and dealers. The adopted definition of financial obligation significantly limits the types of transactions that issuers and obligated persons will need to identify and assess for materiality, and focuses the amendments on debt, debt-like, and debt-related obligations of issuers and obligated persons. The narrowed definition of financial obligation, which only covers those obligations that are debt, debt-like, or debt-related, will result in fewer financial obligations that issuers and obligated persons will need to review for materiality, and should help alleviate commenter concerns about disclosing a material financial obligation within ten business days. In addition, though the period for reporting the incurrence of a material financial obligation does not begin until the date on which the financial obligation is incurred, the Commission understands that most material terms of a financial obligation are typically known to the issuer or obligated person prior to the date of its incurrence. Accordingly, issuers and obligated persons could begin the process of assessing whether a particular obligation should be disclosed pursuant to paragraph (b)(5)(i)(C)(
With respect to commenter concerns about the burdens of summarizing the terms of material financial obligations, issuers and obligated persons could consider amending existing disclosure policies and procedures to address the process for evaluating the disclosure of material financial obligations. Amended policies and procedures, in addition to industry practices that may develop, could help issuers and obligated persons streamline the process of disclosing material financial obligations to EMMA, and ease time and cost burdens associated with identifying, assessing, and disclosing material financial obligations.
Commenters asked whether a series of related financial obligations could be considered material due to their aggregate par amount, though none of the constituent obligations would be material on its own.
When an issuer or obligated person is considering whether a series of related transactions is a single incurrence or has been incurred at different points in time for legitimate business purposes for determining materiality under the amendments, such issuer or obligated person must consider all relevant facts and circumstances. An example of the type of facts and circumstances that could indicate that a series of related transactions were incurred separately for legitimate business purposes would be if the series of financial obligations satisfy the requirements set forth in the U.S. Department of Treasury regulations and guidance governing what constitutes a single issue of municipal securities under the IRC.
Some commenters recommended that the Commission provide guidance on
Commenters observed that the Commission did not prescribe the form of a notice made pursuant to new paragraph (b)(5)(i)(C)(
The Commission acknowledges commenter concerns regarding what form the notice should take. However, given the diversity of issuers and obligated persons, and in light of the structure of the Rule, the Commission believes at this time that market participants are best suited to consider developing best practices in this area to assist issuers and obligated persons and their advisors in carrying out the objective of the amendments, which is to facilitate the timely delivery of important information to investors and other market participants about issuers' and obligated persons' financial obligations.
In the Proposing Release, the Commission defined the term “financial obligation” to mean a debt obligation, lease, guarantee, derivative instrument, or monetary obligation resulting from a judicial, administrative, or arbitration proceeding,
Many commenters criticized the proposed definition of “financial obligation,” characterizing it as overbroad and vague.
Not all commenters, however, were critical of the proposed definition of the term “financial obligation.”
The purpose of the amendments is to facilitate investors' and other market participants' access to timely disclosure of important information related to an issuer's or obligated person's material financial obligations that could impact an issuer's or obligated person's liquidity, overall creditworthiness, or an existing security holder's rights (
As adopted, “financial obligation” means a debt obligation; derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation; or a guarantee of either a debt obligation or a derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation. The term financial obligation does not include municipal securities as to which a final official statement has been provided to the MSRB consistent with Rule 15c2-12.
As discussed below, the definition of the term “financial obligation” does not include ordinary financial and operating liabilities incurred in the normal course of an issuer's or obligated person's business, only an issuer's or obligated person's debt, debt-like, and debt-related obligations.
For a description of commenter arguments that the term “financial obligation” should distinguish between debt and ordinary financial or operating matters,
As proposed, the term “debt obligation” was intended to capture the short-term and long-term debt obligations of an issuer or obligated person under the terms of an indenture, loan agreement, or similar contract that will be repaid over time.
A number of commenters supported the Commission's proposal to require disclosure of debt obligations.
The Commission continues to believe that the definition of “financial obligation” should include debt obligations because such obligations and their terms could adversely affect the rights of existing security holders, including the seniority status of such security holders, or impact the creditworthiness of an issuer or obligated person.
In the Proposing Release, the Commission proposed “lease” as a separate element of the definition of “financial obligation.”
Commenters criticized the inclusion of leases, without limitation, in the definition of “financial obligation” as
The Commission agrees with commenters that, as proposed, the term “lease” was too broad. Accordingly, the Commission believes that it is appropriate to limit the Rule's coverage of leases to those that operate as vehicles to borrow money.
As discussed above, the proposed term “debt obligation” did not include leases because the Commission included the term “lease” as a separate item in the definition of “financial obligation.”
Moreover, in the context of Rule 15c2-12, the Commission is not limiting the term “debt obligation” to debt as it may be defined for state law purposes, but instead is applying it more broadly to circumstances under which an issuer or obligated person has borrowed money. Debt, as defined for state law purposes, “ordinarily means general obligation debt. Typically, the limitation is interpreted to exclude revenue bonds, special fund obligations, and other debt which is not backed by the full faith and credit of the [issuer] coupled by the unlimited power to levy an ad valorem tax to pay such debt.”
For a discussion of when a debt obligation is incurred for purposes of the Rule,
In the Proposing Release, the Commission included the phrase “that will be repaid over time” when discussing the term “debt obligation.” As adopted, the Rule does not include the phrase “that will be repaid over time” to avoid any suggestion that there is a temporal consideration regarding the repayment period of a short-term or long-term debt obligation that could be used to distinguish an obligation that is
As adopted, the term “debt obligation” includes short-term and long-term debt obligations of an issuer or obligated person under the terms of an indenture, loan agreement, lease, or similar contract.
With respect to leases that do not operate as vehicles to borrow money, the Commission agrees with commenters that the burden of assessing their materiality and disclosing such leases within ten business days would not justify the benefit of such disclosures. While the Commission continues to believe that lease arrangements that are not vehicles to borrow money might be relevant to the general financial condition of an issuer or obligated person, the Commission also believes that such lease arrangements do not warrant inclusion in the Commission's definition of “financial obligation” because they generally do not represent competing debt of the issuer or obligated person.
A determination of whether a lease is a “debt obligation” should be based on the substance of the arrangement, not its label. Accordingly, any type of lease arrangement could, under the appropriate facts and circumstances, be a “debt obligation” and be subject to disclosure under the Rule, if it is entered into as a vehicle to borrow money and is material.
As proposed, the term “derivative instrument” was intended to capture any swap, security-based swap, futures contract, forward contract, option, any combination of the foregoing, or any similar instrument to which an issuer or obligated person is a counterparty.
The Commission continues to believe derivative instruments should be included in the adopted definition of the term “financial obligation” because such instruments could adversely impact an issuer's or obligated person's liquidity and overall creditworthiness, or adversely affect security holders.
The term “derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation” is not limited to derivative instruments incurred by issuers or obligated persons solely to hedge the interest rate of a debt obligation or to hedge the value of a debt obligation to be incurred in the future.
The Commission believes that a debt obligation is “planned” at the time the issuer or obligated person incurs the related derivative instrument if, based on the facts and circumstances, a reasonable person would view it likely or probable that the issuer or obligated person will incur the related yet-to-be-incurred debt obligation at a future date. In the Commission's view, it would be likely or probable that an issuer or obligated person will incur a future debt obligation if, for example, the relevant derivative instrument would serve no economic purpose without the future debt obligation (regardless of whether the future debt obligation is ultimately incurred).
For a discussion of when a forward starting interest rate swap is “incurred,”
Factors relevant to whether an issuer's or obligated person's debt obligation is “planned” might include, but are not be limited to, whether: (1) The documents evidencing the relevant derivative instrument explicitly or implicitly assume a future debt obligation; (2) the legislative body of the issuer or obligated person has taken any preliminary (
As proposed, the term “guarantee” was intended to capture a contingent financial obligation of the issuer or obligated person to secure obligations of a third-party or obligations of the issuer or obligated person.
As adopted, the term “financial obligation” is defined to include a guarantee of a debt obligation or a derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation. The Commission's refinement of this aspect of the definition of “financial obligation” is generally responsive to commenter requests for greater clarity as to the scope of guarantees covered by the term “financial obligation” and consistent with commenter sentiment that the Rule only cover guarantees that relate to debt, debt-like, or debt-related
The Commission continues to believe that the guidance provided in the Proposing Release regarding the term “guarantee” accurately sets forth the coverage of guarantee of a debt obligation or derivative instrument entered into in connection with, pledged as security or a source of payment for, an existing or planned debt obligation by the Rule.
A guarantee of a debt obligation or a derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation could raise two disclosures under the Rule—one for the guarantor and one for the beneficiary of the guarantee. Specifically, if an issuer or obligated person incurs a material guarantee, such guarantee would be subject to disclosure under the Rule, as amended. For an issuer or obligated person that is the beneficiary of a guarantee provided in connection with a debt obligation or a derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation, the Commission believes that, generally, such beneficiary issuer or obligated person should assess whether such guarantee is a material term of the underlying debt obligation or derivative instrument and, if so (and if the underlying debt obligation or derivative instrument is material), disclose the existence of such guarantee under the Rule.
As proposed, the term “monetary obligation resulting from a judicial, administrative, or arbitration proceeding” was included in the definition of “financial obligation” because the Commission believed that the requirement to pay such an obligation could adversely impact an issuer's or obligated person's overall creditworthiness and liquidity, and adversely affect security holders.
Moreover, commenters argued that monitoring the numerous judicial, administrative, and arbitration proceedings to which they are party would be overly burdensome and would require the expenditure of a significant amount of issuer and obligated person time and financial and personnel resources.
The Commission is revising the definition of the term “financial obligation” to exclude the term “monetary obligation resulting from a judicial, administrative, or arbitration proceeding.” The Commission believes that, though a monetary obligation resulting from a judicial, administrative, or arbitration proceeding might be relevant to the general financial condition of an issuer or obligated person, such obligations do not typically impact the rights or interests of security holders as issuers and obligated persons generally have reserve funding or insurance to cover such costs, with such funding and insurance typically being reflected in their financial statements.
Accordingly, at this time, the Commission does not believe that monetary obligations resulting from judicial, administrative, or arbitration proceedings raise the same concerns regarding ready and prompt access to information about their existence as the other types of obligations included in the adopted definition of financial obligation. Therefore, the Commission is removing the term “monetary obligation resulting from a judicial, administrative, or arbitration proceeding” from the term “financial obligation.”
As proposed and adopted, the term financial obligation does not include municipal securities as to which a final official statement has been provided to the MSRB consistent with Rule 15c2-12.
Commenters also requested that the Commission revise the proposed language to include an exclusion from disclosure under paragraph (b)(5)(i)(C)(
The Commission is adopting as proposed the amendment to add new paragraph (b)(5)(i)(C)(
As the Commission stated in the Proposing Release, although the occurrence of the events listed in paragraph (b)(5)(i)(C)(
Two commenters recommended that “default” be revised to “event of default,” arguing that “default” was vague while “event of default” is usually defined in transaction documents.
One commenter proposed revising “modification of terms” to “modification of material terms”
One commenter stated that the “other similar events” language was too vague
Some commenters argued that “reflect financial difficulties” was vague and encouraged the Commission to provide additional guidance to prevent a flood of event notices to EMMA.
The Commission continues to believe that the “reflect financial difficulties” qualifier is appropriate. The Commission believes that the term is not vague, as the concept of “reflecting financial difficulties” has been used in paragraphs (b)(5)(i)(C)(
Issuers and obligated persons may consider disclosing the occurrence of events that do not reflect financial difficulties as a matter of best practice if they believe investors would find those occurrences important.
Some commenters stated their belief that paragraph (b)(5)(i)(C)(
As discussed below, the amendments will only affect those continuing disclosure agreements entered into on or after the compliance date for these amendments. Issuers and obligated persons with a continuing disclosure agreement entered into on or after the compliance date must disclose, pursuant to paragraph (b)(5)(i)(C)(
The Commission did not receive any comments on its proposed technical amendment to paragraph (b)(5)(i)(C)(
The amendments to Rule 15c2-12 will impact only those continuing disclosure agreements entered into in connection with Offerings that occur on or after the compliance date of these amendments.
Additionally, in the Proposing Release, the Commission stated that the amendments would apply to continuing disclosure agreements that are entered into in connection with Offerings occurring on or after the compliance date of the amendments.
In the Proposing Release, the Commission proposed a compliance date three months after the final adoption of the amendments. Several commenters argued that the proposed compliance period of three months after adoption was insufficient.
The Rule, as amended, contains “collection of information requirements” within the meaning of the Paperwork Reduction Act of 1995 (“PRA”).
In the Proposing Release, the Commission provided estimates of the burden of complying with the proposed amendments to the Rule and solicited comments on those estimates and the collection of information requirements. On April 26, 2018, the Commission published a notice soliciting comment
Discussed below is the revised Paperwork Reduction Act analysis for Rule 15c2-12. First, the Commission provides a summary of the collection of information required under Rule 15c2-12 prior to these amendments, the amendments to Rule 15c2-12 as proposed, and the amendments to Rule 15c2-12 as adopted. Second, the Commission summarizes the use of the information collected under the Rule. Third, the Commission discusses the respondents subject to a collection of information requirement under the Rule. Fourth, the Commission discusses the burdens under the Rule prior to these amendments, estimated burdens in the Proposing Release, and the revised burdens under Rule 15c2-12 as it applies to broker-dealers, issuers of municipal securities, and the MSRB. Finally, the Commission discusses the costs under the Rule prior to these amendments, estimated costs in the Proposing Release, and the revised costs under Rule 15c2-12 to broker-dealers, issuers of municipal securities, and the MSRB.
Paragraph (b) of Rule 15c2-12 requires a dealer acting as a Participating Underwriter in an Offering: (1) To obtain and review an official statement “deemed final” by an issuer of the securities, except for the omission of specified information, prior to making a bid, purchase, offer, or sale of municipal securities; (2) in non-competitively bid offerings, to send, upon request, a copy of the most recent preliminary official statement (if one exists) to potential customers; (3) to contract with the issuer to receive, within a specified time, sufficient copies of the final official statement to comply with the Rule's delivery requirement, and the requirements of the rules of the MSRB; (4) to send, upon request, a copy of the final official statement to potential customers for a specified period of time; and (5) before purchasing or selling municipal securities in connection with an offering, to reasonably determine that the issuer or obligated person has undertaken, in a written agreement or contract for the benefit of holders of such municipal securities, to provide annual filings, event notices, and failure to file notices (
Under paragraph (b)(5)(i)(C) of Rule 15c2-12, dealers acting as Participating Underwriters in Offerings are required to reasonably determine that the issuer or obligated person has undertaken in a continuing disclosure agreement to provide event notices to the MSRB, in an electronic format as prescribed by the MSRB, in a timely manner not in excess of ten business days, when any of the following events with respect to the securities being offered in an offering occurs: (1) Principal and interest payment delinquencies with respect to the securities being offered; (2) non-payment related defaults, if material; (3) unscheduled draws on debt service reserves reflecting financial difficulties; (4) unscheduled draws on credit enhancements reflecting financial difficulties; (5) substitution of credit or liquidity providers, or their failure to perform; (6) adverse tax opinions, the issuance by the I.R.S. of proposed or final determinations of taxability, Notices of Proposed Issue or other material notices or determinations with respect to the tax status of the security, or other material events affecting the tax status of the security; (7) modifications to rights of security holders, if material; (8) bond calls, if material, and tender offers; (9) defeasances; (10) release, substitution, or sale of property securing repayment of the securities, if material; (11) rating changes; (12) bankruptcy, insolvency, receivership or similar event of the obligated person; (13) consummation of a merger, consolidation, or acquisition, acquisition involving an obligated person or the sale of all or substantially all of the assets of the obligated person, other than in the ordinary course of business, the entry into a definitive agreement to undertake such an action or the termination of a definitive agreement relating to any such actions, other than pursuant to is terms, if material; and (14) appointment of a successor or additional trustee or the change of name of a trustee, if material.
Under the proposed amendments, the Commission proposed to add two additional event notices that a dealer acting as a Participating Underwriter in an Offering must reasonably determine that an issuer or an obligated person has undertaken, in a written agreement or contract for the benefit of holders of
For purposes of the proposed amendments, the Commission proposed to define the term “financial obligation” to mean a (i) debt obligation; (ii) lease; (iii) guarantee; (iv) derivative instrument; or (v) monetary obligation resulting from a judicial, administrative, or arbitration proceeding. As proposed to be defined, the term financial obligation did not include municipal securities as to which a final official statement has been provided to the Municipal Securities Rulemaking Board consistent with Rule 15c2-12.
In response to comments received and as discussed in Section III.A., the Commission has revised its proposed amendments to Rule 15c2-12. The two additional events as paragraphs (b)(5)(i)(C)(
However, the definition of the term “financial obligation” has been narrowed and is now defined as a (i) debt obligation; (ii) derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation; or (iii) guarantee of (i) or (ii). The terms “lease” and “monetary obligation resulting from a judicial, administrative, or arbitration proceeding” have been removed; the term “derivative instrument” has been limited to those “entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation”; and the term “guarantee” has been limited to guarantees of a “debt obligation” or “derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation.” As discussed above in Section III.A.2., these terms were removed or narrowed in response to comments and in order to reduce the burden of complying with the amendments.
The adopted amendments would provide dealers with timely access to important information about municipal securities that they can use to carry out their obligations under securities laws, thereby reducing the likelihood of antifraud violations. This information could be used by individual and institutional investors; underwriters of municipal securities; other market participants, including dealers, analysts, municipal securities issuers, the MSRB, vendors of information regarding municipal securities, the Commission and its staff, and the public generally.
In November 2015, OMB approved an extension without change of the approved collection of information associated with the Rule. The approved paperwork collection associated with Rule 15c2-12 applies to dealers, issuers of municipal securities, and the MSRB. The paperwork collection associated with these adopted amendments would apply to the same respondents. Under the Rule prior to these amendments, the Commission estimated that the number of respondents impacted by the paperwork collection associated with the Rule consists of approximately 250 dealers and 20,000 issuers.
The Commission estimates the aggregate information collection burden for the amended Rule to consist of the following:
In the Proposing Release, consistent with prior estimates, the Commission estimated that approximately 250 dealers potentially could serve as Participating Underwriters in an offering of municipal securities.
Under the Rule prior to these amendments, the Commission has estimated that the total annual burden on all 250 dealers is 22,500 hours (90 hours per dealer per year). This estimate is the sum of two separate burdens: (1) 2,500 hours per year for 250 dealers (10 hours per dealer per year) to reasonably determine that the issuer or obligated person has undertaken, in a written agreement or contract, for the benefit of holders of such municipal securities, to provide continuing disclosure documents to the MSRB, and (2) 20,000 hours per year for 250 dealers (80 hours per dealer per year) serving as Participating Underwriters to determine whether issuers or obligated persons have failed to comply, in all material respects, with any previous undertakings in a written contract or agreement specified in paragraph (b)(5)(i) of the Rule.
In the Proposing Release, the Commission stated it did not expect the
However, because the proposed amendments would add two events notices to paragraph (b)(5)(i)(C) of the Rule, the Commission estimated that the amendments to the Rule would result in an increase of 2,500 hours per year (10 hours per dealer per year) for dealers to determine whether issuers or obligated persons have failed to comply, in all material respects, with any previous undertakings in a written contract or agreement specified in paragraph (b)(5)(i) of the Rule. Using the Commission's prior estimate of 20,000 hours per year (80 hours per dealer per year) as a baseline for this burden,
Therefore, in the Proposing Release, the Commission estimated that the total annual burden of dealers acting as a Participating Underwriter in an Offering would increase by 2,500 hours to 25,000 hours annually (100 hours per dealer per year).
The Commission received no comments on its estimate that dealers would continue to incur a burden of 2,500 hours per year (10 hours per dealer per year) to reasonably determine that the issuer or obligated person has undertaken, in a written agreement or contract, for the benefit of holders of municipal securities, to provide continuing disclosure documents to the MSRB. However, as discussed in further detail below, the Commission is revising its method for calculating the PRA burden on dealers. Accordingly, this estimate is being changed to reflect the new calculation method.
The Commission received several comments on its estimate that the amendments, by adding two event notices to paragraph (b)(5)(i)(C) of the Rule, would increase the burden on dealers by 2,500 hours (10 hours per dealer per year) to determine whether issuers or obligated persons have failed to comply, in all material respects, with any previous undertakings in a written contract or agreement specified in paragraph (b)(5)(i) of the Rule. One commenter stated that because the amendments were “substantially overbroad in scope,” they would subject dealers acting as Participating Underwriters in Offerings to “enormous burdens” beyond what had been estimated.
Commenters also criticized the Commission's prior estimate, predating the proposed amendments, that dealers would incur a burden of 20,000 hours per year (80 hours per dealer per year) to determine whether issuers or obligated persons have failed to comply, in all material respects, with any previous undertakings in a written contract or agreement specified in paragraph (b)(5)(i) of the Rule.
The Commission has considered the comments received and in response is revising its method to calculate the PRA burden for dealers under Rule 15c2-12. In doing so, the Commission is also revising (1) its estimate that dealers would continue to incur a burden of 2,500 hours per year (10 hours per dealer per year), to reasonably
In prior PRA submissions, the Commission calculated the PRA burden on dealers on a collective, rather than per issuance, basis, primarily focusing on the number of dealers acting as Participating Underwriters in Offerings. However, in response to comments,
Using this new method of calculation, the Commission is revising its estimate that dealers would continue to incur a burden of 2,500 hours per year (10 hours per dealer per year), to reasonably determine that the issuer or obligated person has undertaken, in a written agreement or contract, for the benefit of holders of municipal securities, to provide continuing disclosure documents to the MSRB.
The Commission is also revising its estimate that the amendments, by adding two event notices to paragraph (b)(5)(i)(C) of the Rule, would increase the burden on dealers by 2,500 hours per year (10 hours per dealer per year) to determine whether issuers or obligated persons have failed to comply, in all material respects, with any previous undertakings in a written contract or agreement specified in paragraph (b)(5)(i) of the Rule. Under the new method of calculation, the Commission believes that the amendments will, on average, amount to an additional one hour burden per issuance of municipal securities, resulting in an annual increased burden on all dealers of 13,658 hours (approximately 55 hours per year per dealer).
Finally, the Commission is revising its prior estimates, predating the proposed amendments, that the total annual burden for dealers to determine whether issuers or obligated persons have failed to comply, in all material respects, with any previous undertakings in a written contract or agreement specified in paragraph (b)(5)(i) of the Rule is 20,000 hours (80 hours per dealer per year). No commenter provided an estimate for this burden. Under the new method of calculation, the Commission believes that dealers will incur 8 hours of burden per issuance of municipal securities to make this determination, resulting in an
Accordingly, under the Commission's revised estimates, the total annual burden for all dealers acting as Participating Underwriters in Offerings will be 126,337 hours (approximately 505 hours per dealer per year),
In the Proposing Release, the Commission estimated that each dealer acting as a Participating Underwriter in an Offering would incur a one-time paperwork burden to have its internal compliance attorney prepare and issue a notice advising its employees about the proposed revisions to Rule 15c2-12, including any updates to policies and procedures affected by the proposed amendments.
One commenter expressed concern that the Commission's estimate of the one-time burden on dealers acting as Participating Underwriters in Offerings was too low.
Accordingly, the Commission estimates that the 250 dealers acting as a Participating Underwriter in Offerings would incur a one-time burden of five hours each, for a total one-time, first year burden of 1,250 hours for all dealers.
Under the amendments to Rule 15c2-12 as adopted, the total burden on all dealers would be 127,587 hours for the first year
The amendments, as adopted, result in a paperwork burden on issuers of municipal securities. For this purpose, issuers include issuers of municipal securities described in paragraph (f)(4) of the Rule and obligated persons described in paragraph (f)(10) of the Rule.
Under the Rule prior to these amendments and in the Proposing Release, the Commission estimated that 20,000 issuers of municipal securities annually submit to the MSRB approximately 62,596 annual filings, 73,480 event notices, and 7,063 failure to file notices.
The Commission proposes to modify paragraph (b)(5)(i)(C) of the Rule, which presently requires a dealer acting as a Participating Underwriter in an Offering to reasonably determine that an issuer or obligated person has entered into a continuing disclosure agreement that, among other things, contemplates the submission of an event notice to the MSRB in an electronic format upon the occurrence of any events set forth in the Rule. The Rule prior to these amendments contained fourteen such events. The adopted amendments to this paragraph of the Rule add two new event disclosure items: New paragraph (b)(5)(i)(C)(
Under the Rule prior to these amendments, the Commission estimates that issuers prepare and submit annually: (1) 73,480 event notices, with each notice taking approximately two hours to prepare and submit; (2) 62,596 annual filings, with each filing taking approximately seven hours to prepare and submit; and (3) 7,063 failure to file notices, with each notice taking approximately two hours to prepare and submit.
In the Proposing Release, the Commission estimated that the amendments to the Rule would result in an increase to the annual total burden of issuers. Specifically, the Commission estimated that the proposed amendment in paragraph (b)(5)(i)(C)(
The Commission received several comments relating to the estimates of the Paperwork Reduction Act burden on issuers.
Commenters also criticized the Commission for failing to account for the burden created by what they termed the ambiguity of the term “material.” One commenter argued that the Commission, by refusing to give explicit guidance as to materiality, will force issuers to “review voluminous, often inconsistent court decisions and administrative orders in an attempt to give clarity to the term.”
These commenters generally contended that the burden of complying with the proposed amendments was far greater than the Commission's estimates. One commenter, after surveying its members, estimated that the time needed to ensure compliance with the proposed amendments would be approximately seven hours per event notice required to be filed with the MSRB under the proposed rule.
In response to comments, the Commission is revising, from two hours to four hours, its estimate of the average time needed for an issuer to prepare and submit an event notice to the MSRB in an electronic format, including time to actively monitor the need for filing. The Commission believes this change, which recognizes an increased annual burden estimate on issuers of 151,360 hours
However, the Commission is not changing its estimate that the amendments to the Rule will result in 2,200 additional event notices filed annually, raising the total number of event notices prepared by issuers annually to approximately 75,680. The Commission believes this estimate remains appropriate because of the substantial narrowing of the definition of financial obligation from the definition proposed in Proposing Release.
Under the amendments to Rule 15c2-12 as adopted, the total burden on issuers to submit continuing disclosure documents would be 755,018 hours.
Under the Rule prior to these amendments, the Commission estimated that the MSRB incurred an annual burden of approximately 12,699 hours to collect, index, store, retrieve, and make available the pertinent documents under the Rule.
The Commission received no comments on these estimates. However, the Commission is revising these estimates to correspond with updated estimates provided by the MSRB. The Commission now estimates that the MSRB incurs an annual burden of approximately 19,500 hours to collect, index, store, retrieve, and make available the pertinent continuing disclosure documents under the Rule.
Under the Rule prior to these amendments and in the Proposing Release, the Commission made no estimate of the burden on dealers effecting transactions in the secondary market to comply with Rule 15c2-12. Two commenters characterized this as an omission.
The Commission continues to believe that neither the adopted amendments nor Rule 15c2-12 prior to amendment contains “collection of information requirements” within the meaning of the PRA on dealers effecting transactions in the secondary market. Rule 15c2-12(c) requires only that a dealer acting in the secondary market have “procedures in place that provide reasonable assurance that it will receive prompt notice of any event disclosed pursuant to paragraph (b)(5)(i)(C), paragraph (b)(5)(i)(D), and paragraph (d)(2)(ii)(B)” of the Rule. To the extent that dealers effecting transactions in the secondary market review and disclose material to customers, those associated burdens stem from antifraud provisions and MSRB rules that are not subject to this PRA analysis.
The Commission estimates that the ongoing annual aggregate information collection burden for the Rule after giving effect to the amendments would be 900,855 hours.
In the Proposing Release, the Commission stated that it did not expect dealers to incur any additional external costs associated with the proposed amendments to the Rule because the proposed amendments do not change the obligation of dealers under the Rule to reasonably determine that the issuer or obligated person has undertaken, in a written agreement or contract, for the benefit of holders of such municipal securities, to provide continuing
Also in the Proposing Release, the Commission stated that it did not expect the MSRB to incur any additional external costs associated with the proposed amendments to the Rule. The Commission believed that the MSRB would not incur additional external costs specifically associated with modifying the indexing system to accommodate the amendments to the Rule because the MSRB would implement those changes internally. The Commission received no comments on this estimate. After consultation of the Commission staff with MSRB staff, the Commission continues to believe that this estimate is appropriate. Additionally, in the Proposing Release, the Commission estimated that the MSRB expends $10,000 annually in hardware and software costs for the MSRB's EMMA system.
Under the amendments to Rule 15c2-12 as adopted, the total external costs to dealers would be zero and the total external costs to the MSRB would be $520,000 annually. Table 4 below summarizes the Commission's PRA external cost estimates for dealers and the MSRB in the 2015 PRA Notice (the Commission's most recent estimates prior to these amendments), the Proposing Release, and the Adopting Release.
In the Proposing Release, the Commission stated that it believes issuers generally would not incur external costs associated with the preparation of event notices filed under the amendments, because issuers would generally prepare the information contained in the continuing disclosures internally.
However, the Commission recognized that issuers would be subject to some costs associated with the amendments to the Rule if they paid third parties to assist them with their continuing disclosure responsibilities. Under the Rule prior to these amendments, the Commission estimated that up to 65% of issuers may use designated agents to submit some or all of their continuing disclosure documents to the MSRB for a fee estimated to range from $0 to $1,500 per year, with an average total annual cost incurred by issuers using the services of a designated agent of $9,750,000.
The Commission received no comments on this estimate. The Commission continues to believe that the amendments will result in an increase of 2,200 event notices filed
In the Proposing Release, the Commission also estimated that issuers would incur some cost to revise their current template for continuing disclosure agreements to reflect the proposed amendments to the Rule. The Commission stated its belief that continuing disclosure agreements tend to be standard form agreements. As it did in response to prior amendments to the Rule in 2010,
The Commission did not estimate any other external costs incurred by issuers as a result of the proposed amendments. Several commenters disagreed, stating that due to the proposed broad definition of financial obligation and commenters' view that there was lack of clarity around materiality, issuers would rely, in some part, on outside counsel to assist in the monitoring, evaluating, preparing, and filing of the event notices required by the proposed amendments.
The Commission has considered these comments and is revising its cost estimates for issuers. As discussed in Section III.A.2., the Commission has clarified and narrowed the scope of the amendments which will substantially lessen the burden on issuers of monitoring, evaluating, preparing, and filing event notices required by the amendments to the Rule. The Commission expects that any external costs that would have been incurred by issuers under the proposed amendments would be similarly reduced by those changes. The Commission also believes that the adopted amendments, by focusing on debt, debt-like, and debt-related obligations, will reduce the need for issuers to obtain outside counsel to assist with an event notice.
However, the Commission acknowledges that some issuers may retain outside counsel to assist in the evaluation and preparation of some of the more complex event notices as a result of the amendments to the Rule. As discussed above, the Commission estimates that the amendments will generate 2,200 additional event notices a year.
Under the amendments to Rule 15c2-12 as adopted, the total cost to issuers would be $16,229,000 annually,
As an SRO subject to 17 CFR 240.17a-1 (Rule 17a-1 under the Exchange Act), the MSRB is required to retain records of the collection of information for a period of not less than five years, the first two years in an easily accessible place. Broker-dealers registered pursuant to Exchange Act Section 15 are required to comply with the books and records requirements of 17 CFR 240.17a-3 and 240.17a-4 (Exchange Act Rules 17a-3 and 17a-4). Participating Underwriters and dealers transacting business in municipal securities are subject to existing recordkeeping requirements of the MSRB.
Any collection of information pursuant to the amendments to the Rule would be a mandatory collection of information.
The collection of information pursuant to the amendments to the Rule would not be kept confidential and would be publicly available.
The Commission is adopting, substantially as proposed, amendments to Rule 15c2-12 under the Exchange Act to revise the list of event notices that a Participating Underwriter in an Offering must reasonably determine an issuer or obligated person has agreed to provide to the MSRB in its continuing disclosure agreement.
As discussed above, the main difference between the Rule as proposed
As discussed in the Proposing Release, the need for more timely disclosure of information in the municipal securities market about financial obligations is highlighted by market developments beginning in 2009 which feature the increasing use of direct placements by issuers and obligated persons as financing alternatives to public offerings of municipal securities.
The use of direct placements or other debt obligations may benefit issuers and obligated persons in the form of convenience or lower borrowing costs relative to a public offering of municipal securities—there is typically no requirement to prepare an offering document or obtain a credit rating, liquidity facility, or bond insurance.
However, under the current regulatory framework, investors and other market participants may not have any access or timely access to information related to the incurrence of financial obligations and other events included in the amendments, despite their potential impact on the risks of, and returns to, municipal securities.
As described in Section III.A and the Proposing Release, numerous market participants, including the MSRB, FINRA, academics, and industry groups, have encouraged issuers and obligated persons to voluntarily disclose information about certain financial obligations.
The Commission is mindful of the costs imposed by and benefits obtained from its rules. In the Proposing Release, the Commission solicited comments on all aspects of the costs and benefits associated with the amendments, including any effect the Rule may have on efficiency, competition, and capital formation. The Commission has considered these comments, which are discussed in more detail in the sections below, and continues to believe that the amendments to Rule 15c2-12 will facilitate investors' and other market participants' access to more timely and informative disclosure in the secondary market about financial obligations of issuers and obligated persons. The Commission believes that more timely and informative disclosure allows investors to make more informed investment decisions and analysts to produce more informed analyses, and such disclosure can therefore enhance transparency in the municipal securities market and investor protection. The discussion below elaborates on the likely costs and benefits of the amendments and their potential impact on efficiency, competition, and capital formation.
Where possible, the Commission has attempted to quantify the costs, benefits, and effects on efficiency, competition, and capital formation that may result
Similarly, due to an absence of data, the Commission is unable to provide a reasonable estimate of the potential change in borrowing costs issuers or obligated persons may experience as a result of the amendments. For example, loan rate determinants include the characteristics of the issuer or obligated person (
There are other factors that also limit the Commission's ability to quantify the future economic impact of the amendments. For example, recent federal tax law changes may also affect borrowing costs of issuers and obligated persons as well as investor demand for municipal debt, among other things.
To assess the economic impact of the amendments to Rule 15c2-12, the Commission is using as its baseline the existing regulatory framework for municipal securities disclosure, including Rule 15c2-12 prior to these amendments, and current relevant MSRB rules.
As discussed above and in the Proposing Release, the need for more timely and informative disclosure of financial obligations is highlighted by market developments beginning in 2009, which feature the increasing use of direct placements by issuers and obligated persons as financing alternatives to public offerings of municipal securities. Below is an overview of the current state of the municipal securities market and issuers' and obligated persons' use of direct placements based on data from the Federal Reserve Board's Flow of Funds data,
According to Flow of Funds data, the notional amount of the total municipal securities outstanding in the U.S. was $3.84 trillion as of the end of the first quarter of 2018.
However, the involvement of commercial banks in the municipal capital markets has increased dramatically in terms of purchases of municipal securities and extensions of loans to state and local governments and their instrumentalities.
The incurrence of financial obligations can result in an increase in the issuer's or obligated person's outstanding debt, negatively affecting the liquidity and creditworthiness of the issuer or obligated person and the prices of their outstanding municipal securities. However, currently, there is a lack of secondary market disclosure about these financial obligations, a topic that has been discussed by the MSRB, certain market participants, and academics.
As discussed above, the Commission first adopted Rule 15c2-12 in 1989 as a means reasonably designed to prevent fraud in the municipal securities market by enhancing the quality, timing, and dissemination of disclosures in the municipal securities primary market.
Even if investors and other market participants have access to disclosure about an issuer's or obligated person's financial obligations, such access may not be timely if, for example, the issuer or obligated person has not submitted annual financial information or audited financial statements to EMMA in a timely manner or does not frequently issue debt that results in a final official statement being provided to EMMA. Typically, as discussed above and in the Proposing Release, investors and other market participants do not have access to an issuer's or obligated person's annual financial information or audited financial statements until several months or up to a year after the end of the issuer's or obligated person's applicable fiscal year, and a significant amount of time could pass before an issuer's or obligated person's next primary offering subject to Rule 15c2-12.
Furthermore, to the extent the information about financial obligations is disclosed and accessible to investors and other market participants, such information currently may not include certain details about the financial obligations. Specifically, disclosure of a financial obligation in an issuer's or obligated person's financial statements may be a line item about the amount of the financial obligation, and may not provide investors and other market participants with information relating to an issuer's or obligated person's agreement to covenants, events of default, remedies, priority rights, or other similar terms of a financial obligation, any of which affect security holders, if material.
MSRB rules do not address the disclosure of the events covered in the amendments. However, as described above and in the Proposing Release, the MSRB has highlighted the increased use of direct placements as a financing alternative.
In March 2016, the MSRB published a regulatory notice requesting comment on a concept proposal to require municipal advisors to disclose information regarding the direct placements of their municipal entity clients to EMMA.
GASB released in April 2018 Statement No. 88, Certain Disclosures Related to Debt, including Direct Borrowings and Direct Placements.
GASB Statement No. 88 also “requires that additional essential information related to debt be disclosed in notes to financial statements, including unused lines of credit, assets pledged as collateral for the debt, and terms specified in debt agreements related to significant events of default with finance-related consequences, significant termination events with finance-related consequences, and significant subjective accelerations clauses.”
As discussed more fully above, although GASB Statement No. 88 could result in the disclosure of more information related to debt disclosed in issuers' or obligated persons' audited financial statements consistent with that
Recent changes to federal tax laws
Second, a decline in the federal corporate income tax rate may increase the interest rates on issuers' or obligated persons' direct placements, reducing the demand for direct placements. Prior to the changes in the federal tax law, municipal issuers and obligated persons enjoyed lower interest rates than their corporate counterparts in part because banks benefitted from tax-free interest income. The reduction in the corporate income tax rate diminishes the relative benefit for the municipal tax exemption, making direct placements less attractive.
Third, as discussed above, because the new tax law eliminated state and local governments' ability to use tax-exempt bonds to advance refund outstanding bonds, some issuers and obligated persons may be incentivized to use complex strategies and derivative products to refund outstanding bond issues,
Under current rules, certain inefficiencies may arise in the municipal securities market as a result of the lack of timely disclosure of information on important credit events. As discussed above and in the Proposing Release, currently investors and other market participants may not learn about the new information related to the issuer's or obligated person's financial obligations for months or over a year after the end of the issuer's or obligated person's fiscal year. Since the market is not able to incorporate into prices the most recent credit risk information about issuers and obligated persons, the securities offered by issuers or obligated persons of different credit risks could be priced identically. For example, all else equal, an issuer or obligated person that incurs a large amount of undisclosed financial obligations may be more likely to default on its payment obligations than one that does not. However, in the absence of public disclosure, market participants could assign the same price to both issuers' or obligated persons' securities. Mispricing on the basis of undisclosed risks could lead to inefficiency in the allocation of financial resources across high- and low-risk issuers and obligated persons.
Rule 15c2-12 prior to these amendments may create competitive advantages for certain market participants. As discussed above and in the Proposing Release, because the market might not be able to differentiate securities offered by high-risk issuers and obligated persons from those offered by low-risk issuers and obligated persons because of lack of disclosures under Rule 15c2-12 prior to these amendments, low-risk issuers and obligated persons could be subject to disadvantages if they are unable to credibly demonstrate to market participants that they are low-risk. As another example, municipal securities investors are also in a disadvantageous position relative to private lenders. As discussed above and in the Proposing Release, the terms of a financial obligation incurred by an issuer or obligated person may include covenants that alter the debt payment priority structure of the issuer's or obligated person's outstanding securities, or give the lender a lien on assets or revenues that were previously pledged to secure repayment of an issuer's or obligated person's outstanding municipal securities, effectively diluting existing security holders' claims and adversely affecting their contractual rights without their knowledge. In the Commission's view, the existence of these scenarios does not represent a fully competitive market.
The price inefficiencies in the municipal securities market and the disparity in available information for different types of investors could result in inefficient allocation of capital. For example, as mentioned above, the inability of the market to differentiate high-risk issuers or obligated persons from low-risk ones could lead to a mismatch of investors to securities appropriate for their risk preferences, leading to suboptimal allocation of capital.
The Commission has considered the potential costs and benefits associated with the amendments and the comments received regarding the proposed amendments.
At the same time, the Commission continues to recognize that the amendments will introduce costs to relevant parties, including issuers, obligated persons, dealers, and lenders. However, it is the Commission's belief that the costs are justified in light of the benefits. A discussion of the economic costs and benefits of the amendments, including the effects on efficiency, competition, and capital formation, is set forth in more detail below.
The Commission believes that these amendments may yield several benefits to municipal securities investors. First, the amendments will facilitate investors' access to more timely and informative disclosures about an issuer's or obligated person's financial obligations, and thereby assist them in making more informed investment decisions when trading in the secondary market.
As discussed in the Proposing Release, the information regarding the events described in the amendments is relevant for investors' investment decision making. For example, the incurrence of a financial obligation that results in an increase or change in an issuer's or obligated person's outstanding debt may impact the issuer's or obligated person's liquidity and overall creditworthiness. For another example, an agreement to covenants, events of default, remedies, priority rights, or other similar terms of a financial obligation, any of which affect security holders, may result in, among other things, contingent liquidity and credit risks that potentially impact the issuer's or obligated person's liquidity and overall creditworthiness and reduce value for existing security holders.
However, currently, investors and other market participants may not have any access or timely access to information related to the incurrence of financial obligations and other events included in the amendments. For example, investors and other market participants may not learn of these events if the issuer or obligated person does not provide annual financial information or audited financial statements to EMMA or does not subsequently issue debt in a primary offering subject to Rule 15c2-12 that results in the provision of a final official statement to EMMA. Further, even if investors and other market participants have access to disclosure about these events, such access may not be timely if, for example, the issuer or obligated person has not submitted annual financial information or audited financial statements to EMMA in a timely manner or does not frequently issue debt that results in a final official statement being provided to EMMA. Typically, as discussed above and in the Proposing Release, investors and other market participants do not have access to an issuer's or obligated person's annual financial information or audited financial statements until several months or up to a year after the end of the issuer's or obligated person's applicable fiscal year, and a significant amount of time could pass before an issuer's or obligated person's next primary offering subject to Rule 15c2-12.
Moreover, to the extent the information about financial obligations is disclosed and accessible to investors and other market participants, such information currently may not include certain details. Specifically, the disclosure may include only the existence of the financial obligation that the issuer or obligated person has incurred, but not specified material terms of the financial obligation that can affect security holders, including those terms that, for example, affect security holders' priority rights. Therefore, existing security holders could be making investment decisions without the knowledge that the value of the securities and their contractual rights have been adversely impacted, and potential investors could be buying these securities at an inflated price. As such, the current level of disclosure regarding an issuer's or obligated person's financial obligations is neither timely nor adequately informative.
To the extent that investors in the municipal securities market rely on credit ratings as a meaningful indicator of credit risk, the recent efforts of certain credit rating agencies to collect information from issuers and obligated persons about the incurrence of direct placements may help improve the accuracy of credit ratings and mitigate potential mispricing in the municipal securities market.
Under the amendments to Rule 15c2-12, Participating Underwriters in an Offering are required to reasonably determine that an issuer or obligated person has agreed in its continuing disclosure agreement to provide notices for the new events within ten business days. Consequently, pursuant to the amendments, municipal securities investors and other market participants will have access to the specified disclosures within ten business days as opposed to waiting for the issuer's or obligated person's next primary offering subject to Rule 15c2-12, waiting for the release of annual financial information or audited financial statements, or having no access to such information at all. In addition, the event notices generally should include a description of material terms of the financial obligations, which might include the date of incurrence, principal amount, maturity and amortization, interest rate, if fixed, or method of computation, if variable (and any default rates),
Second, more timely and informative disclosures may reduce the information disadvantage investors have relative to other more informed parties such as issuers, obligated persons, counterparties, and lenders, and enhance their protection. As discussed above and in the Proposing Release, for example, a bank loan agreement could alter the debt payment priority structure of the issuer's or obligated person's outstanding securities, or give the lender a lien on assets or revenues that also secure the repayment of an issuer's or obligated person's outstanding municipal securities, diluting existing security holders' claims and adversely affecting their contractual rights. However, under the Rule prior to these amendments, existing security holders may not learn about such events and may therefore be unable to take any actions they might have taken had they been informed, such as exiting their position. More timely and informative disclosure of the events covered in the amendments should promote a fairer information environment that allows current investors to monitor whether their contractual rights have been negatively impacted by undisclosed financial obligations and take appropriate actions.
In the Proposing Release, the Commission discussed that the amendments would benefit issuers and obligated persons because greater transparency regarding an issuer's or obligated person's financial obligations might lead to a decrease in borrowing costs, particularly the costs associated with their public debt. One comment the Commission received urged the Commission to further study borrowing costs, because the commenter asserted that the Commission “does not genuinely address systemic increased borrowing costs that may result from this rule.”
As discussed in the Proposing Release, in the context of corporate disclosure, economic theories suggest information asymmetry can lead to an adverse selection problem and reduce the level of liquidity.
The Commission continues to believe that the additional disclosures are likely to reduce borrowing costs for issuers or obligated persons. The Commission has further examined academic studies on the relationship between disclosures and municipal borrowing costs in light of commenter concerns. While relatively limited, most of the available studies on disclosure and municipal borrowing costs provide evidence that more disclosure regulation or stringent accounting and auditing requirements are associated with lower municipal borrowing costs. This literature also supports the Commission's view that disclosure reduces information asymmetry and the cost of capital.
For additional reference to borrowing costs in corporate securities markets,
Also in response to the commenter's concern, the Commission further considered the amendments' impact on the cost of issuers' and obligated persons' private debt, including direct placements and other financial obligations. As discussed in the Proposing Release, the amendments should promote competition for investment opportunities between municipal securities investors and private lenders by reducing information asymmetry.
Overall, the Commission believes that the amendments could benefit issuers and obligated persons by reducing the cost of both publicly issued and privately placed debt including direct placements and other financial obligations. The Commission also recognizes that borrowing costs could increase in some cases as a result of the amendments, which would constitute a cost to issuers and obligated persons. More discussion on the cost and overall impact of the amendments will be provided in a later section.
The Commission continues to believe that the amendments will help rating agencies and municipal analysts gain access to more updated information about the issuer's and obligated person's credit and financial position at a lower cost. As discussed in the Proposing Release, rating agencies and municipal analysts have stated on a number of occasions that direct placements can have credit implications for ratings on an issuer's or obligated person's outstanding municipal securities.
The Commission expects that, under the amendments, issuers and obligated persons will experience an increase in administrative costs from undertaking in their continuing disclosure agreements to produce the additional event notices. As discussed above,
As discussed in Section IV.D.2 and Section IV.E.2, after carefully considering the comments received, the Commission is revising certain estimates of the annual paperwork burden and related cost for all issuers and obligated persons.
Another area of inquiry is the potential of the amendments and resulting disclosures to increase the cost of financial obligations for issuers and obligated persons. In response to the comment mentioned above,
In addition, as also discussed above and in the Proposing Release, existing banking literature suggests that lenders develop proprietary information about the borrower during a lending relationship because they actively engage in information gathering and
Therefore, to the extent that the disclosure of material terms of financial obligations may reduce lenders' information advantage, there could be incentive for lenders to increase loan rates as a way of compensating for the lost benefit. However, as stated above, the amendments do not specify or dictate the form and content of the disclosure.
One commenter expressed concerns over “the systemic increased borrowing costs that may result from this rule could drastically affect [the] entire municipal direct placement market and possibly shut many smaller actors out of the market completely.”
Regarding the commenter's concern on the amendments' impact on small issuers and obligated persons, the Commission recognizes that certain small issuers and obligated persons that are particularly reliant on private debt including direct placements or other financial obligations may choose to stay out of the public debt market should they find the additional disclosure becomes too burdensome or costly; however, the amendments should not significantly affect their ability to borrow in the private market given that this has been their primary funding source. Therefore, the Commission disagrees with the commenter's assessment that amendments' impact on the municipal direct placement market may “possibly shut many smaller actors out of the market completely.”
Currently, the Commission is unable to provide reasonable estimates of the potential change in borrowing costs as a result of the amendments. The same comment also expressed concern that the Commission's attempts to quantify the amendments' potential impact on borrowing costs may be insufficient.
First, issuers' and obligated persons' borrowing costs include two components—the cost of public debt and the cost of privately placed debt including direct placements and other financial obligations. Both types of costs may vary significantly depending on a number of factors. For example, yields for municipal bonds offered to the public are affected by, among other things, the size of the issuance, credit rating, underwriter reputation, maturity and credit enhancement for bonds. Loan rate determinants include the characteristics of the issuer or obligated person (
Second, the amendments' impact on borrowing costs may vary significantly across different types of issuers or obligated persons. For example, under the current Rule, securities issued by issuers or obligated persons that have incurred a significant amount of previously undisclosed financial obligations may be priced the same by the market as those that did not incur such undisclosed financial obligations. However, if these financial obligations were incurred after the implementation of the amendments, the enhanced disclosure would allow the market to incorporate the credit risk information and differentiate the two types of issuers or obligated persons when pricing their outstanding securities. As a result, all else equal, the issuers or obligated persons that incurred financial obligations could experience an increase in borrowing costs (
Finally, recent changes to federal tax laws
Pursuant to Rule 15c2-12, a dealer acting as a Participating Underwriter in an Offering has an existing obligation to contract to receive the final official statement.
As a practical matter, dealers' obligations under the Rule 15c2-12 amendments will include verifying that the continuing disclosure agreement contains an undertaking by the issuer or obligated person to provide the additional event notices to the MSRB, verifying whether the issuer or obligated person has complied with its prior undertakings, and verifying whether the final official statement includes, among other things, an accurate description of the issuer's or obligated person's prior compliance with continuing disclosure obligations.
As discussed in Section IV.D.1, the Commission is revising its estimate of the one-time and annual burden on dealers.
Under the amendments, lenders may incur costs stemming from the disclosure about financial obligations and the terms of the agreements creating such obligations. As discussed above and in the Proposing Release, lenders may enjoy certain priority rights in these financial arrangements which may not be publicly disclosed or reflected in the price of the issuer's or obligated person's outstanding municipal securities. However, as discussed above, while the increased level of disclosure may reduce lenders' information advantage over other investors, it does not eliminate this advantage because private lenders such as banks actively engage in information gathering and monitoring of borrowers and thus develop proprietary information during the lending relationship. Disclosure is also unlikely to alter the lender's senior status in the debt priority queue. To the extent that the benefits from a previously undisclosed financial arrangement are reduced by the increased disclosure, lenders will incur a cost, but such a cost translates into benefits to investors, because the benefit originally accrued to lenders at the expense of investors in municipal securities.
In addition, since the amendments may decrease the costs incurred by issuers and obligated persons in connection with the issuance of public debt and increase the demand for public issuance, lenders may experience reduced investment opportunities, or may have to decrease loan rates in order to stay competitive, either of which
The Rule 15c2-12 amendments will increase the type of event notices submitted to the MSRB which may result in the MSRB incurring costs associated with such additional notices. As discussed in Section IV.D.3, after further discussion with the MSRB, the Commission is revising its burden estimate for the MSRB to implement the necessary modifications to EMMA.
The Rule 15c2-12 amendments have the potential to affect efficiency, competition, and capital formation by improving the timeliness and informativeness of municipal securities disclosure and reducing information asymmetry in the market.
As discussed above and in the Proposing Release, lack of disclosure can lead to information asymmetry and mispricing. When the market is not able to incorporate the most recent credit risk information about issuers and obligated persons in the pricing of municipal securities, such prices will not reflect the true risk associated with any particular security. The securities offered by low-risk issuers or obligated persons could be undervalued and the ones offered by high-risk issuers or obligated persons overvalued, and investors may not be able to distinguish between the two.
In addition, as we have also discussed before, at least one rating agency currently requires issuers and obligated persons to provide notification and documentation of the incurrence of certain financial obligations, including direct placements, in order to maintain their credit ratings, a process that may involve duplicative costs, because each rating agency would have to implement a similar process to collect the same information, and issuers and obligated persons would have to provide identical responses multiple times.
The Commission also believes that by potentially reducing information asymmetries between municipal securities investors and other more-informed market participants, including issuers, obligated persons and lenders, the Rule 15c2-12 amendments can promote competition in the municipal debt market. One commenter expressed concern that disclosure of pricing terms of loans in ten business days may “set an unrealistic expectation among other obligated persons as to the appropriate pricing for their direct purchase loan transactions” and early disclosures may have an “anti-competitive” effect that may increase pricing by setting a “benchmark” for certain transactions.
The Commission also stated in the Proposing Release that more timely and informative disclosure could reduce a lender's competitive advantage over municipal securities investors under the Rule prior to these amendments, and facilitate competition for investment opportunities in the municipal debt market.
In addition, the amendments to Rule 15c2-12 may also promote competition among issuers or obligated persons looking for funding. For example, all else equal, the issuers or obligated persons that have incurred a large amount of undisclosed financial obligations are likely to be riskier than those that have not. However, under the Rule prior to these amendments,
The Commission continues to believe that the Rule 15c2-12 amendments can help facilitate capital formation by improving market efficiency and liquidity. As illustrated by the example above, mispricing and market inefficiencies can lead to a situation where the securities offered by the high-risk issuers and obligated persons—those that incurred a large amount of undisclosed financial obligations—are priced identically to those offered by the low-risk issuers and obligated persons. The inability to differentiate the two types of investment opportunities by the market could lead to underinvestment in the low-risk securities and overinvestment in the other, leading to suboptimal allocation of capital. By increasing the timeliness and informativeness of disclosure, the amendments can reduce mispricing in the market and thus reduce potential for price inefficiencies, resulting in improved allocation of capital.
More timely and informative disclosure could also improve market liquidity and therefore facilitate capital formation. According to academic research, disclosure policy influences market liquidity because uninformed investors, concerned about asymmetric information, price protect themselves in their securities transactions by offering to sell at a premium or buy at a discount. This price protection could be manifested in higher bid-ask spreads and reduced market liquidity.
In addition to the Rule 15c2-12 amendments, the Commission has considered several reasonable alternatives, which are discussed below.
Instead of these amendments, the Commission could encourage issuers and obligated persons to voluntarily disclose on an ongoing basis the new events covered in the amendments. A number of commenters recommended the Commission further explore this approach. For example, one commenter challenged the Commission's characterization of the existing level of the voluntary disclosure as limited, arguing that such conclusion was “hastily” drawn and recommended further exploration of voluntary disclosure.
While the Commission recognizes the benefits of voluntary disclosure for issuers and obligated persons, we continue to believe that voluntary disclosure alone is not sufficient for the level of investor protection the amendments are designed to achieve. The current level of the voluntary disclosure of issuers' and obligated persons' financial obligations is not sufficient, and that is why, as discussed in Section II, municipal market participants, the MSRB, and industry groups have made continuous efforts to elicit more disclosure.
Issuers and obligated persons could be provided additional time (
As discussed in Section II and Section III.1.i.c, commenters were concerned that ten business days was not enough time to disclose material financial obligations. The Commission is adopting a narrower definition of “financial obligation” than proposed, which will reduce the burden on issuers, obligated persons, and dealers by significantly limiting the number of transactions that they will need to identify and assess for materiality. The narrower definition could partially alleviate this concern.
Under the alternative timeline approach, issuers' and obligated persons' operational burden could be slightly reduced but their substantive obligation to provide disclosure would remain. Moreover, investors and other market participants would receive less timely disclosure. The alternative would thus provide investors with less protection, and the market would not operate as efficiently as it might be under the amendments.
As discussed above,
Under this alternative, the disclosure-related costs associated with the amendments would be eliminated for small issuers and obligated persons and their disclosure and borrowing practices would stay the same as the baseline scenario. However, it is possible that over time their securities could become further mispriced and potentially less attractive to investors compared to those issued by issuers and obligated persons that provide more disclosure. But issuers and obligated persons would be able to provide voluntary disclosure if they believe the benefits of more accurate pricing offset the cost of disclosure.
Under this alternative, investors in municipal securities that are exempt from disclosure requirements under the final rules would not experience the full benefits discussed above because they would not receive more timely and informative disclosures about small issuers' and obligated persons' financial obligations than they would otherwise receive under the amendments, as adopted.
Another alternative approach is to adopt, as proposed, the broader definition of financial obligation. In the Proposing Release, the Commission defined the term “financial obligation” to mean a debt obligation, lease, guarantee, derivative instrument, or monetary obligation resulting from a judicial, administrative, or arbitration proceeding, but not include municipal securities as to which a final official statement has been provided to the MSRB consistent with Rule 15c2-12.
As discussed above, the Commission is narrowing the definition of “financial obligation.” As adopted, “financial obligation” means a debt obligation; derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation; or a guarantee of either a debt obligation or a derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation. The term financial obligation does not include municipal securities as to which a final official statement has been provided to the MSRB consistent with the Rule.
If the amendments to the Rule were adopted as proposed, investors and other participants would receive more information related to issuers' and obligated persons' financial obligations because of the proposed broader definition of “financial obligation.” This alternative could allow credit rating agencies and municipal analysts to produce more accurate ratings and forecasts, and could yield greater improvements in market efficiency. This alternative could also allow those investors capable of interpreting broader information about issuers' and obligated persons' obligations to make more informed financial decisions. However, the Commission also recognizes that a higher volume of disclosure may not benefit all investors equally. The Commission believes that the information disclosed under this alternative would include information about obligations incurred in an issuer's or obligated person's normal course of operations that do not impact an issuer's or obligated person's liquidity, overall creditworthiness, or an existing security holder's rights and thus may not be as relevant to investment decisions.
The Commission certified, under section 605(b) of the Regulatory Flexibility Act,
Pursuant to the Exchange Act, and particularly Sections 2, 3(b), 10, 15(c), 15B, 17 and 23(a)(1) thereof, 15 U.S.C. 78b, 78c(b), 78j, 78
Brokers, Reporting and recordkeeping requirements, Securities.
For the reasons set out in the preamble, title 17, chapter II, of the Code of Federal Regulations is amended as follows.
15 U.S.C. 77c, 77d, 77g, 77j, 77s, 77z-2, 77z-3, 77eee, 77ggg, 77nnn, 77sss, 77ttt, 78c, 78c-3, 78c-5, 78d, 78e, 78f, 78g, 78i, 78j, 78j-1, 78k, 78k-1, 78
The additions read as follows.
(b) * * *
(5)(i) * * *
(C) * * *
(
(
(f) * * *
(11)(i) The term
(A) Debt obligation;
(B) Derivative instrument entered into in connection with, or pledged as security or a source of payment for, an existing or planned debt obligation; or
(C) Guarantee of paragraph (f)(11)(i)(A) or (B).
(ii) The term
By the Commission.
The following appendix will not appear in the Code of Federal Regulations.
1. Letter from John M. McNally, Hawkins Delafield & Wood LLP, to Brent J. Fields, Secretary, Commission, dated March 21, 2017 (“Hawkins Letter”).
2. Letter from Jody Johnson, to Brent J. Fields, Secretary, Commission, dated April 2, 2017 (“Johnson Letter”).
3. Letter from Clifford M. Gerber, President, National Association of Bond Lawyers, to Shagufta Ahmed, Desk Officer for the Securities and Exchange Commission, Office of Information and Regulatory Affairs, Office of Management and Budget, and to Brent J. Fields, Secretary, Commission, dated April 11, 2017 (“NABL OMB Letter”).
4. Letter from Lynnette Kelly, Executive Director, Municipal Securities Rulemaking Board, to Brent J. Fields, Secretary, Commission, dated April 14, 2017 (“MSRB Letter”).
5. Letter from David Lisante, J.D. Candidate 2017, Cornell Law School, to Brent J. Fields, Secretary, Commission, dated April 20, 2017 (“Lisante Letter”).
6. Letter from Ken Martin, Assistant Commissioner Financial Services/CFO, Texas Higher Education Coordinating Board, to Brent J. Fields, Secretary, Commission, dated May 1, 2017 (“THECB Letter”).
7. Letter from Tyler Brown, J.D. Candidate, Boston College Law School, to Brent J. Fields, Secretary, Commission, dated May 1, 2017 (“Brown Letter”).
8. Letter from Michael Phemister, Vice President, Treasury Management, Dallas Fort Worth International Airport, to Brent J. Fields, Secretary, Commission, dated May 4, 2017 (“DFW Letter”).
9. Letter from Michael A. Genito, Commissioner of Finance, City of White Plains, New York, to Brent J. Fields, Secretary, Commission, dated May 5, 2017 (“White Plains Letter”).
10. Letter from Brian C. Massey, Finance Director, Outagamie County, Wisconsin, to Brent J. Fields, Secretary, Commission, dated May 5, 2017 (“Outagamie Letter”).
11. Letter from Erich Mueller, Finance Director, City of Troutdale, Oregon, to Brent J. Fields, Secretary, Commission, dated May 8, 2017 (“Troutdale Letter”).
12. Letter from Neal D. Suess, President/CEO, Loup River Public Power District, to Brent J. Fields, Secretary, Commission, dated May 9, 2017 (“Loup Power Letter”).
13. Letter from Tracy Ginsburg, Executive Director, Texas Association of School Business Officials, to Brent J. Fields, Secretary, Commission, dated May 9, 2017 (“TASBO Letter”).
14. Letter from Marina Scott, City Treasurer, Salt Lake City, Utah, to Brent J. Fields, Secretary, Commission, dated May 9, 2017 (“Salt Lake City Letter”).
15. Letter from Chad D. Gee, Superintendent, Yorktown Independent School District, Texas, to Brent J. Fields, Secretary, Commission, dated May 9, 2017 (“Yorktown SD Letter”).
16. Letter from Julie Egan, Chair, and Lisa Washburn, Chair, Industry Practices Procedures, National Federation of Municipal Analysts, to Brent J. Fields, Secretary, Commission, dated May 10, 2017 (“NFMA Letter”).
17. Letter from Robert Scott and Keith Dagen, Co-Chairs, Financial Reporting and Regulatory Response Committee, Government Finance Officers Association of Texas, to Brent J. Fields, Secretary, Commission, dated May 10, 2017 (“GFOA TX Letter”).
18. Letter from Jeff N. Heiner, President, Board of Education, Ogden City School District, Utah, to Brent J. Fields, Secretary, Commission, dated May 10, 2017 (“Ogden Letter”).
19. Letter from Martin W. Bates, Ph.D., J.D., Superintendent, and Terry Bawden, Board President, Granite School District, Utah, to Brent J. Fields, Secretary, Commission, dated May 11, 2017 (“Granite SD Letter”).
20. Letter from Grant Whitaker, President & CEO, Utah Housing Corporation, to Brent J. Fields, Secretary, Commission, dated May 11, 2017 (“UHC Letter”).
21. Letter from Ann Mackiernan, Chief Financial Officer, Tualatin Hills Park & Recreation District of Oregon, to Brent J. Fields, Secretary, Commission, dated May 12, 2017 (“THPRD Letter”).
22. Letter from Arthur J. “Grant” Lacerte, Vice President and General Counsel, Kissimmee Utility Authority, Florida, to Brent J. Fields, Secretary, Commission, dated May 12, 2017 (“Kissimmee Letter”).
23. Letter from Dr. Marcelo Cavazos, Superintendent, Arlington Independent School District, Texas, to Brent J. Fields, Secretary, Commission, dated May 12, 2017 (“Arlington SD Letter”).
24. Letter from Cynthia A. Nichol, Chief Financial Officer, Port of Portland, Oregon, to Brent J. Fields, Secretary, Commission, dated May 12, 2017 (“Port Portland Letter”).
25. Letter from Kristin M. Bronson, City Attorney, City and County of Denver, Colorado, to Brent J. Fields, Secretary, Commission, dated May 12, 2017 (“Denver Letter”).
26. Letter from Ted Wheeler, Mayor, City of Portland, Oregon, to Brent J. Fields, Secretary, Commission, dated May 12, 2017 (“Portland Letter”).
27. Letter from Michele Trongaard, Assistant Superintendent for Finance and Operation, Wylie Independent School District, Texas, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Wylie SD Letter”).
28. Letter from Dorothy Donohue, Deputy General Counsel, Securities Regulation, Investment Company Institute, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“ICI Letter”).
29. Letter from Dennis M. Kelleher, President & CEO, Better Markets, Inc., to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“BM Letter”).
30. Letter from David W. Osburn, General Manager, Oklahoma Municipal Power Authority, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“OMPA Letter”).
31. Letter from Kurt J. Nagle, President and CEO, American Association of Port Authorities, to Brent J. Fields, Secretary,
32. Letter from Leslie M. Norwood, Managing Director and Associate General Counsel, Securities Industry Financial Markets Association, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“SIFMA Letter”).
33. Letter from Clifford M. Gerber, President, National Association of Bond Lawyers, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“NABL Letter”).
34. Letter from Charisse Mosely, Deputy City Controller, City of Houston, Texas, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Houston Letter”).
35. Letter from Joanne Wamsley, Vice President for Finance and Deputy Treasurer, Arizona State University, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“AZ Universities Letter”).
36. Letter from Leo Karwejna, Managing Director and Chief Compliance Officer, PFM, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“PFM Letter”).
37. Letter from Robert W. Doty, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Doty Letter”).
38. Letter from Noreen Roche-Carter, Chair, Tax and Finance Task Force, Large Public Power Council, Sacramento, California, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“LPPC Letter”).
39. Letter from Rebecca L. Peace, Deputy Executive Director and Chief Counsel, Pennsylvania Housing Finance Agency, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“PHFA Letter”).
40. Letter from John J. Wagner, Kutak Rock LLP, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Kutak Rock Letter”).
41. Letter from Michael Nicholas, Chief Executive Officer, Bond Dealers of America, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“BDA Letter”).
42. Letter from Kevin M. Burke, President and CEO, Airports Council International, North America, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“ACI Letter”).
43. Letter from Marty Dreischmeier, Chief Financial Officer, WPPI Energy, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“WPPI Letter”).
44. Letter from Diana Pope, Director, Financing and Investment Division, and Lee McElhannon, Director, Bond Finance, Financing and Investment Division, Georgia State Financing and Investment Commission, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“GA Finance Letter”).
45. Letter from Ken Miller, NAST President, Treasurer, State of Oklahoma, National Association of State Treasurers, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“NAST Letter”).
46. Letter from Timothy Cameron, Esq. Head, and Lindsey Weber Keljo, Esq., Managing Director and Associate General Counsel, Asset Management Group, SIFMA, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“SIFMA AMG Letter”).
47. Letter from Cristeena G. Naser, Vice President, Center for Securities, Trust & Investments, American Bankers Association, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“ABA Letter”).
48. Letter from Robert W. Scott, Director of Finance, City of Brookfield, Wisconsin, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Brookfield Letter”).
49. Letter from Richard Doyle, City Attorney, City of San Jose, California, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“San Jose Letter”).
50. Letter from Donna Murr, President, National Association of Health and Educational Facilities Finance Authorities, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“NAHEFFA Letter”).
51. Form Letter from Issuers in the State of Oregon (“Form Letter”).
52. Letter from Christopher Alwine, Head of Municipal Money Market and Bond Groups, The Vanguard Group, Inc., to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Vanguard Letter”).
53. Letter from Susan Gaffney, Executive Director, National Association of Municipal Advisors, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“NAMA Letter”).
54. Letter from Emily S. Brock, Director, Federal Liaison Center, Government Finance Officers Association, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“GFOA Letter”).
55. Letter from Walker R. Stapleton, State Treasurer, and Ryan Parsell, Deputy Treasurer, State of Colorado, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“CO Treasury Letter”).
56. Letter from Glenn Hegar, Texas Comptroller of Public Accounts, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“TCPA Letter”).
57. Letter from Tracy Olsen, Business Administrator, Nebo School District, Utah, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“Nebo SD Letter”).
58. Letter from Garth Rieman, Director of Housing Advocacy and Strategic Initiatives, National Council of State Housing Agencies, to Brent J. Fields, Secretary, Commission, dated May 15, 2017 (“NCSHA Letter”).
59. Letter from Paula Stuart, Chief Executive Officer, Digital Assurance Certification, to Brent J. Fields, Secretary, Commission, dated May 16, 2017 (“DAC Letter”).
60. Letter from Sophia D. Skoda, Director of Finance, East Bay Municipal Utility District, California, to Brent J. Fields, Secretary, Commission, dated May 17, 2017 (“East Bay Letter”).
61. Letter from Keith Paul Bishop, Former California Commission of Corporations, to Brent J. Fields, Secretary, Commission, dated June 1, 2017 (“Bishop Letter”).
62. Letter from Michael Cohen, Director, California Department of Finance, to Brent J. Fields, Secretary, Commission, dated June 28, 2017 (“CA Finance Letter”).
63. Letter from Clifford M. Gerber, President, National Association of Bond Lawyers, to Brent J. Fields, Secretary, Commission, dated August 29, 2017 (“NABL II Letter”).
64. Letter from Alexandra M. MacLennan, President, National Association of Bond Lawyers, to Brent J. Fields, Secretary, Commission, dated June 13, 2018 (“NABL III Letter”).
65. Letter from School Improvement Partnership to Pamela Dyson, Director/Chief Information Officer, Commission, dated May 31, 2018 (“SIP Letter”).
Environmental Protection Agency (EPA).
Proposed rule.
The Environmental Protection Agency (EPA) is proposing three distinct actions, including Emission Guidelines for Greenhouse Gas Emissions from Existing Electric Utility Generating Units (EGUs). First, EPA is proposing to replace the Clean Power Plan (CPP) with revised emissions guidelines (the Affordable Clean Energy (ACE) rule) that inform the development, submittal, and implementation of state plans to reduce greenhouse gas (GHG) emission from certain EGUs. In the proposed emissions guidelines, consistent with the interpretation described in the proposed repeal of the CPP, the Agency is proposing to determine that heat rate improvement (HRI) measures are the best system of emission reduction (BSER) for existing coal-fired EGUs. Second, EPA is proposing new regulations that provide direction to both EPA and the states on the implementation of emission guidelines. The new proposed implementing regulations would apply to this action and any future emission guideline issued under section 111(d) of the Clean Air Act (CAA). Third, the Agency is proposing revisions to the New Source Review (NSR) program that will help prevent NSR from being a barrier to the implementation of efficiency projects at EGUs.
•
•
•
•
For questions about this proposed action, contact Mr. Nicholas Swanson, Sector Policies and Programs Division (Mail Code D205-01), Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, Research Triangle Park, North Carolina 27711; telephone number: (919) 541-4080; fax number: (919) 541-4991; and email address:
EPA may publish any comment received to its public docket. Multimedia submissions (audio, video, etc.) must be accompanied by a written comment. The written comment is considered the official comment and should include discussion of all points you wish to make. EPA will generally not consider comments or comment contents located outside of the primary submission (
The
Throughout this proposal, EPA is soliciting comment on numerous aspects of the proposed rule. EPA has indexed each comment solicitation with an alpha-numeric identifier (
Accordingly, we ask that commenters include the corresponding identifier when providing comments relevant to that comment solicitation. We ask that commenters include the identifier in either a heading, or within the text of each comment (
EPA is proposing the Affordable Clean Energy (ACE) rule as a replacement to the CPP (promulgated on October 23, 2015, 80 FR 64662), which sets GHG emission guidelines for existing EGUs. This proposal relies in part on the legal analysis presented in the CPP repeal that was proposed on October 16, 2017, 82 FR 48035. In the proposed repeal, EPA asserted that the BSER in the CPP exceeded EPA's authority because it established the BSER using measures that applied to the power sector as whole, rather than measures that apply at and to, and can be carried out at the level of, individual facilities. This proposed action aligns with EPA's statutory authority and obligation because, as EPA has done in the dozens of NSPSs issued to date, the BSER is to be determined by evaluating technologies or systems of emission reduction that are applicable to, at, and on the premises of the facility for an affected source. This proposal will ensure that coal-fired power plants (the most carbon dioxide (CO
Accordingly, the proposed ACE rule consists of three discrete sections. First, EPA is proposing to determine the BSER for existing EGUs based on HRI measures that can be applied at an affected source. EPA also proposes a corresponding emission guideline clarifying the roles of EPA and the states under CAA section 111(d). EPA's primary role in implementing CAA section 111(d) is to provide emission guidelines that inform the development, submittal, and implementation of state plans, and to subsequently determine whether submitted state plans are approvable. Per the CAA, once EPA publishes a final emission guideline, states have the primary role of developing standards of performance consistent with application of the BSER. Congress also expressly required that EPA allow states to consider source-specific factors—including, among other factors, the remaining useful life of the affected source—in applying a standard of performance. In this way, the state and federal roles complement each other as EPA has the authority and responsibility to determine a nationally applicable BSER while the states have the authority and responsibility to establish and apply existing source standards of performance, in consideration of source-specific factors.
Second, EPA is proposing new implementing regulations that apply to this action and any future emission guidelines promulgated under CAA section 111(d). The purpose of proposing new implementing regulations is to harmonize our 40 CFR part 60 subpart B regulations with the statute by making it clear that states have broad discretion in establishing and applying emissions standards consistent with the BSER. The discussion for the proposed revisions is found in Section VII below.
Third, EPA is proposing to give the owners/operators of EGUs more latitude to make the efficiency improvements that are consistent with EPA's proposed BSER without triggering onerous and costly NSR permit requirements. This change will allow states, in establishing standards of performance, to consider HRIs that would otherwise not be cost-effective due to the burdens incurred from triggering NSR. The discussion of this issue is included in Section VII.
As with other regulations of this nature, this notice concludes with a summary of the impacts of this proposal and is supported by a Regulatory Impact Analysis (RIA) that can be found in the docket for this action. As reported in the RIA, EPA evaluated three illustrative policy scenarios modeling HRI at coal-fired EGUs. EPA estimates that there are cost savings under two of the three illustrative scenarios, with average annual compliance costs ranging from a cost savings of about $0.5 billion to a cost of about $0.3 billion. As noted previously, this action is preceded by a proposed repeal of the CPP.
This proposed action has been informed by comments submitted in response to the ANPRM, published December 28, 2017,
In addition to being available in the docket, an electronic copy of this action is available on the internet. Following signature by the EPA Administrator, EPA will post a copy of this proposed action at
When passing and amending the CAA, Congress sought to address and remedy the dangers posed by air pollution to human beings and the environment. While the text of the CAA does not reflect an explicit intent on the part of Congress to address the potential effects of elevated atmospheric GHG concentrations, the Supreme Court in
In 2009, and again in 2016, the EPA Administrator issued findings under sections 202(a) and 231(a)(2)(A) of the Clean Air Act, respectively, that the current, elevated concentrations of six well-mixed GHGs in the atmosphere may reasonably be anticipated to endanger public health and welfare of current and future generations in the
While the market in the power sector is driving GHG emissions down, the EPA, by proposing this emission guideline, is reinforcing the market in many respects and also ensuring that available emission reductions that are not market driven are achieved. Many regulations are promulgated to correct market failures, which otherwise lead to a suboptimal allocation of resources within the free market. Air quality and pollution control regulations address “negative externalities” whereby the market does not internalize the full opportunity cost of production borne by society as public goods such as air quality are unpriced.
While recognizing that optimal social level of pollution may not be zero, GHG emissions impose costs on society, such as negative health and welfare impacts, that are not reflected in the market price of the goods produced through the polluting process. For this regulatory action the good produced is electricity. If a fossil fuel-fired electricity producer pollutes the atmosphere when it generates electricity, this cost will be borne not by the polluting firm but by society as a whole, thus the producer is imposing a negative externality, or a social cost of emissions. The equilibrium market price of electricity may fail to incorporate the full opportunity cost to society of generating electricity. Consequently, absent a regulation on emissions, the EGUs will not internalize the social cost of emissions and social costs will be higher as a result. This regulation will work towards addressing this market failure by causing affected EGUs to begin to internalize the negative externality associated with CO
Further discussion of GHG impacts, as well as the benefits of this proposal, can be found in the RIA for this action. As detailed in Chapter 3 of the RIA, EPA evaluated three illustrative policy scenarios representing ACE. These scenarios are projected to result in a decrease of annual CO
Along with the 111(b) standard, EPA issued, under CAA section 111(d), its “Clean Power Plan,” consisting of GHG emission guidelines for
In March 2017, President Trump issued Executive Order 13873, which among other things, directed EPA to reconsider the CPP. After considering the statutory text, context, legislative history and purpose, and in consideration of EPA's historical practice under CAA section 111 as reflected in its other existing CAA section 111 regulations and of certain policy concerns, EPA proposed to repeal the CPP.
In ACE, EPA is proposing to determine that the BSER for GHG emissions from existing coal-fired EGUs is heat rate improvements that can be applied at the source, consistent with the legal interpretation expressed in the proposed repeal. The Agency is also, in this action, clarifying the respective roles of the states and EPA under CAA section 111(d), including by proposing revisions to the regulations, in 40 CFR part 60 subpart B, implementing that section. Section 111(d)(1) of the CAA states that EPA's “Administrator shall prescribe regulations which shall establish a procedure . . . under which each State shall submit to the Administrator a plan which (A) establishes standards of performance for any existing source for any air pollutant . . . to which a standard of performance under this section would apply if such existing source were a new source, and (B) provides for the implementation and enforcement of such standards of performance.”
As the plain language of the statute provides, EPA's authorized role under CAA section 111(d)(1) is to develop a procedure for states to establish standards of performance for existing sources. Indeed, the Supreme Court has acknowledged the role and authority of states under section 111(d): This provision allows “each State to take the first cut at determining how best to achieve EPA emissions standards within its domain.”
As contemplated by CAA section 111(d)(1), states possess the authority and discretion to establish appropriate standards of performance for existing sources. CAA section 111(a)(1) defines “standard of performance” as “a standard of emissions of air pollutants which reflects” what is colloquially referred to as the “Best System of Emission Reduction” or “BSER”—
In order to effectuate the Agency's role under CAA section 111(d)(1), EPA promulgated implementing regulations in 1975 to provide a framework for subsequent EPA rules and state plans under section 111(d).
In short, under EPA's new proposed regulations implementing CAA section 111(d), which tracks with the existing implementing regulations in this regard, the guideline document serves to “provide information for the development of state plans.” 40 CFR 60.22a(b), with the “emission guideline,” reflecting BSER as determined by EPA, being the principal piece of information states rely on to develop their plans that establish standards of performance for existing sources.
Because the CAA cannot necessarily be applied to GHGs in the same manner as other pollutants,
Additionally, while CAA section 111(d)(1) clearly authorizes states to develop state plans that establish performance standards and provides states with certain discretion in determining appropriate standards, CAA section 111(d)(2) provides EPA specifically a role with respect to such state plans. This provision authorizes EPA to prescribe a plan for a state “in cases where the State fails to submit a satisfactory plan.” CAA section 111(d)(2)(A). EPA therefore is charged with determining whether state plans developed and submitted under section 111(d)(1) are “satisfactory,” and the proposed new implementing regulations at 40 CFR 60.27a accordingly provides timing and procedural requirements for EPA to make such a determination. Just as guideline documents may provide information for states in developing plans that establish standards of performance, they may also provide information for EPA to consider when reviewing and taking action on a submitted state plan, as the new proposed implementing regulations at 40 CFR 60.27a(c) references the ability of EPA to find a state plan as “unsatisfactory because the requirements of (the implementing regulations) have not been met.”
On March 28, 2017, President Trump issued Executive Order 13783, which affirms the “national interest to promote clean and safe development of our Nation's vast energy resources, while at the same time avoiding regulatory burdens that unnecessarily encumber energy production, constrain economic growth, and prevent job creation.”
In a document signed the same day as Executive Order 13783, and published in the
This action proposes a BSER for GHGs from existing EGUs in line with the interpretation presented in the proposed CPP repeal.
Carbon dioxide emissions in the power sector have steadily declined in recent years due to a variety of power industry trends, which are expected to continue. The reduction in power sector CO
In the near-term, according to the U.S. Energy Information Administration's (EIA) 2018 Annual Energy Outlook, “the cumulative effect of increased coal plant retirements, lower natural gas prices and lower electricity demand in the AEO2018 Reference case is a reduction in the projected [CO
In consideration of these ongoing and projected power sector trends and a resulting decline in power sector CO
Because of the rapid pace of these power sector changes, it is difficult for sector analysts to fully account for these changing trends in near-term and long-term sector-wide projections. This means that regulatory decisions made today could be based on information that may very well be outdated within the next several years. If that is the case, work put in by federal and state regulatory agencies—as well as by the affected sources themselves—to address section 111(d) requirements could quickly be overtaken by external market forces which could make those efforts redundant or, even worse, put them in conflict with industry trends that are already reducing CO
EPA's ability to revisit existing regulations is well-grounded in the law. Specifically, EPA has inherent authority to reconsider, repeal or revise past decisions to the extent permitted by law so long as the Agency provides a reasoned explanation. The CAA complements EPA's inherent authority to reconsider prior rulemakings by providing the Agency with broad authority to prescribe regulations as necessary. 42 U.S.C. 7601(a);
In the CPP, EPA stated that EPA's then-concurrent promulgation of standards of performance regulating CO
We explained in the CPP that CAA section 111(d)(1) requires EPA to promulgate regulations under which states must submit state plans regulating “any existing source” of certain pollutants “to which a standard of performance would apply if such existing source were a new source.”
EPA explained in the 111(b) rule (80 FR 64529) that “CAA section 111(b)(1)(A) requires the Administrator to establish a list of source categories to be regulated under section 111. A category of sources is to be included on the list `if in [the Administrator's] judgment it causes, or contributes significantly to, air pollution which may reasonably be anticipated to endanger public health and welfare.' ” This determination is commonly referred to as an “endangerment finding” and that phrase encompasses both the “causes or contributes significantly” component and the “endanger public health and welfare” component of the determination. Then, for the source categories listed under section 111(b)(1)(A), the Administrator promulgates, under section 111(b)(1)(B), “standards of performance for new sources within such category.” EPA further explained that, because EGUs had previously been listed, it was unnecessary to make an additional finding. The Agency also noted that, under section 111(b)(1)(A), findings are category specific and not pollutant specific, so a new finding is not needed with regard to a new pollutant. The Agency further asserted that, even if it were required to make a finding, given the large amount of CO
That CAA section 111(b) rulemaking remains on the books, although EPA is currently considering revising it. Accordingly, it continues to provide the requisite predicate for applicability of CAA section 111(d). Any comments on the issues discussed in this subsection would be more appropriately addressed
As discussed above, EPA's authorized role under CAA section 111(d) is to establish a procedure under which states submit plans establishing standards of performance for existing sources, reflecting the application of the best system of emission reduction that EPA has determined is adequately demonstrated for the source category. In the CPP, EPA determined that the BSER for CO
1. Improving heat rate at affected coal-fired steam generating units;
2. Substituting increased generation from lower-emitting existing natural gas combined cycle units for decreased generation from higher-emitting affected steam generating units; and
3. Substituting increased generation from new zero-emitting renewable energy generating capacity for decreased generation from affected fossil fuel-fired generating units.
As explained in the proposed repeal, after reconsidering the statutory text, context and legislative history, and in consideration of EPA's historical practice under CAA section 111 as reflected in its other existing section 111 regulations, the Agency proposes to return to a reading of section 111(a)(1) (and its constituent term, “best system of emission reduction”) as being limited to emission reduction measures that can be applied to or at an individual stationary source. That is, such measures must be based on a physical or operational change to a building, structure, facility or installation at that source rather than measures the source's owner or operator can implement at another location. For a more detailed discussion of EPA's proposed interpretation, see 82 FR 48039-42.
In proposing ACE, EPA offers additional legal rationale to support its determination that heat-rate improvements constitute the BSER. EPA solicits comment on these additional legal interpretations (Comment C-2).
First, as explained in the CPP preamble, reduced utilization “does not fit within our historical and current interpretation of the BSER.”
Second, as explained in the proposed repeal notice, interpretative constraints that may apply to interpreting CAA section 111(a)(1) (
Under the CAA and applicable regulations, certain preconstruction permits must contain emissions limitations based on application of BACT for certain regulated pollutants. EPA recommends that permitting authorities follow a five-step “top-down” BACT analysis, which calls for all available control technologies for a given pollutant to be identified and ranked in descending order of control effectiveness.
In reviewing our BACT guidance, we have identified additional interpretive constraints that may be applied to CAA section 111. Specifically, in EPA's
In its response to comments, EPA largely based its rejection of the relevance of PSD to BSER on what it saw as the salient distinctions between the sources subject to, and mode of operation of, the two statutory programs. In this regard, EPA spoke of the “distinct context of the PSD program, which involves the case-by-case review of the construction of an
Here, EPA's response disregarded the fact that under CAA section 111(d), the statute explicitly tasks states—not the Administrator—with “establishing standards of performance” for existing sources, and that the statute expressly requires EPA to allow the state to take into account source-specific factors when doing so. A “standard of performance” is defined at section 111(a)(1) as “a standard for emissions of air pollutants which reflects the
Furthermore, speaking of the generation-shifting measures that constituted the second and third “building blocks” of the CPP, EPA asserted that “those measures are part of the business purposes and objectives
EPA rested on its discretionary prerogative: “EPA's policies under CAA section 165 regarding the construction of individual sources are not controlling for purposes of establishing
Third, notwithstanding the relationship between BACT and BSER, we believe that measures “redefining the source” should be excluded from consideration for purposes of CAA section 111(d).
Fourth, the legislative history underlying CAA section 111 confirms that Congress intended this provision to be source oriented. The Senate Committee Report on Senate Bill 4358 explained that “[t]he provisions for new source performance standards [
The proposed interpretive scope of the BSER is reasonable because it focuses the BSER on the performance of the emitting unit itself, rather than the performance of the emitting unit and the transmission system to which it belongs. EPA's area of expertise is control of emissions at the source. EPA is not the expert agency with regard to electricity management. FERC is the expert at the
Also, the proposed interpretive scope of the BSER is reasonable considering the several important economic, policy and technology shifts occurring in the power sector. The first change is being driven by low natural gas prices that make lower carbon-emitting NGCC units more competitive as compared to higher carbon-emitting coal plants. Another important change is driven by both technology changes and by state and national energy policy decisions that have made renewable energy (
These trends have driven down GHG emissions from power plants, which were also key components to the BSER as defined in the CPP. In fact, the analysis that EPA has done for ACE (see RIA), as well as analysis by many others (including EIA), show that these trends have already well outpaced the projections that went into the CPP for many states. For this reason, establishing a BSER on assumptions for generation by various sources that accounts for the continuation of these trends into the future would create significant work for both states and sources that may or may not result in emission reductions from ACE if the actual trends once again prove to be stronger than projected.
While some might suggest that this argues that the BSER in ACE should still follow the same approach as the CPP, adjusting this proposal to be even more stringent ignores the fact that the uncertainties that have resulted in faster than projected emission reductions are also uncertain in the opposite direction. From 2005 to 2008, gas prices experienced several unexpected peaks that were not anticipated. If this were to happen in the future, it would make any rule based on CPP-type assumptions significantly more expensive. Similarly, while the recent past has shown continued advances in renewable cost and performance, it is not certain that those trends will be sustained. It should be noted that federal tax subsidies that have been key to this trend are set to expire over the next several years which may play a role in the future.
Because of these significant uncertainties that can have large impacts on electric reliability and the cost of electricity to consumers, EPA believes that this further supports the unreasonableness of basing the BSER on generation-shifting measures. Regardless of the path that the power sector takes, coal-fired power plants are likely to be an important part of the generation mix for the foreseeable future, therefore EPA believes it is reasonable to ensure that the remaining coal-fired generation (which is also the most CO
EPA believes that a BSER focused on making these plants as efficient as possible is the best way to ensure GHG emission reductions regardless of other factors such as technology changes for other types of generation, changes in fuel price, changes in electricity demand or changes in energy policy that neither environmental regulators nor power companies have the power to control.
EPA is proposing that an affected EGU subject to regulation upon finalization of ACE is any fossil fuel-fired electric utility steam generating unit (
EPA is proposing different applicability criteria than in the CPP to reflect EPA's determination of the BSER for only fossil fuel-fired electric utility steam generating units. In ACE, EPA does not identify a BSER for stationary combustion turbines and IGCC units and, thus, such units are not affected EGUs for purposes of this action (see discussion below in Section V.B). It should be noted, in the CPP's identification of the BSER, no HRIs were identified as the BSER for stationary combustion turbines and IGCC units. Nevertheless, EPA solicits comment on systems of emission reduction that might be the BSER for these types of
CAA section 111(d)(1) directs EPA to promulgate regulations establishing a CAA section 110-like procedure under which states submit state plans that establish “standards of performance” for emissions of certain air pollutants from sources which, if they were new sources, would be subject to new source standards under section 111(b), and that provide for the implementation and enforcement of those standards of performance. The term “standard of performance” is defined in section 111(a)(1) as “a standard for emissions of air pollutants which reflects the degree of emission limitation achievable through the application of the best system of emission reduction [BSER] which (taking into account the cost of achieving such reduction and any nonair quality health and environmental impact and energy requirements) the Administrator determines has been adequately demonstrated.”
Thus, EPA is authorized to determine the BSER for affected sources.
CAA section 111(d)(1) assigns responsibility to the states for establishing standards of performance for affected existing sources—in contrast to section 111(b), which directs EPA to set standards of performance for affected new sources.
In ACE, EPA identified several systems of emission reduction for existing fossil-fuel fired steam generating EGUs (
EPA proposes to identify “heat rate improvements” (which may also be referred to as “efficiency improvements”) as the BSER for existing fossil-fuel fired steam generating EGUs. The basis for this determination is discussed below. A discussion of other potential CO
The U.S. fleet of existing coal-fired EGUs is a diverse group of units with unique individual characteristics, spread across the country. Coal-fired power plants are customized facilities that were designed and built to meet local and regional electricity needs over the past 100 years, with no two plants being identical. Geography and elevation, unit size, coal type, pollution controls, cooling system, firing method and utilization rate are just a few of the parameters that can impact the overall efficiency and performance of individual units. As a result, heat rates of existing coal-fired EGUs in the U.S. vary substantially. The variation in heat rates among EGUs with similar design characteristics, as well as year-to-year variation in heat rate at individual EGUs, indicate that there is potential for HRIs that can improve CO
EPA does not currently have sufficient information on adequately demonstrated systems of emission reduction—including HRI opportunities—for existing natural gas-fired stationary combustion turbines. As such, the Agency is currently unable to determine the BSER for such units. In this action, EPA solicits information on adequately demonstrated systems of GHG emission reduction for such units—especially on the efficiency, applicability, and cost of such systems (Comment C-5). This is discussed in greater detail below.
As mentioned above, EPA proposes in ACE to identify “heat rate improvements” as the BSER for existing steam generating fossil fuel-fired EGUs. Heat rate is a measure of efficiency that is commonly used in the power sector. The heat rate is the amount of energy input, measured in British thermal units (Btu), required to generate one kilowatt-hour (kWh) of electricity. The lower an EGU's heat rate, the more efficiently it operates. As a result, an EGU with a lower heat rate will consume less fuel per kWh generated and emit lower amounts of CO
• Thermodynamic cycle of the boiler;
• Boiler and steam turbine size and design;
• Cooling system type;
• Auxiliary equipment, including pollution controls;
• Operations and maintenance practices;
• Fuel quality; and
• Ambient conditions.
In the CPP, EPA quantified emission reductions achievable through heat rate improvements on a regional basis (
EPA believes that building block 1, as constructed in CPP, does not represent an appropriate BSER, and ACE better reflects important changes in the formulation and application of the BSER in accordance with the CAA. For example, the percent improvement applied as the BSER under CPP was determined at the interconnect-level, and did not take into account remaining useful life or other source-specific factors, which are addressed in this proposed rule.
There are available technologies and equipment upgrades, as well as best operating and maintenance practices, that EGU owners or operators may utilize to improve an EGU's heat rate. In the ANPRM, EPA solicited information on a number of technology and equipment upgrades and good practices (specifically including, but not limited to, those that were listed in Tables 1 and 2 of the ANPRM,
Specifically, the Agency solicited information on: (1) Potential HRIs from technologies and best operating and maintenance practices; (2) costs of deploying the technologies and the best operating and maintenance practices, including applicable planning, capital and operating and maintenance costs; (3) owner and operator experiences deploying the technologies and employing best operating and maintenance practices; (4) barriers to or from deploying the technologies and operating and maintenance practices; and (5) any other technologies or operating and maintenance practices that may exist for improving heat rate, but were not listed in the ANPRM.
EPA received useful information in the comments submitted in response to the ANPRM. Many commenters contended that any evaluation of the HRI potential of the coal-fired EGU fleet must be done on a unit-by-unit basis since the opportunities for HRI are source-specific and dependent upon the individual unit's design, configuration, and operating and maintenance history. Many commenters emphasized the significant influence that the operating mode (
As mentioned above, numerous technologies and equipment upgrades, as well as best operating and maintenance practices (which are discussed in the next section), have been identified as potential measures to improve an EGU's heat rate. In the ANPRM, EPA solicited information on a large number of technology and equipment upgrades and best operating and maintenance practices that have the potential to reduce an EGU's heat rate.
In this action, EPA is proposing to determine that heat rate improvement is the BSER for affected existing coal-fired EGUs and is proposing a list of “candidate technologies” of HRI measures for states to use in establishing standards of performance under CAA section 111(d)(1). States can use the information that EPA provides on the “degree of emission limitation achievable through application of the [BSER]” to establish standards of performance for affected EGUs covered by a state's plan.
The technologies and operating and maintenance practices listed and
The cost to implement an ISB system is relatively inexpensive if the necessary hardware is already installed. The ISB software/control system is often incorporated into the neural network software package mentioned above. As such, the HRIs obtained via installation of neural network and ISB systems are not necessarily cumulative.
The efficiency improvements from installation of intelligent sootblowers are often greatest for EGUs firing subbituminous coal and lignite due to more significant and rapid fouling at those units as compared to EGUs firing bituminous coal.
A boiler feed pump (or boiler feedwater pump) is a device used to pump feedwater into a boiler. The water may be either freshly supplied or returning condensate produced from condensing steam produced by the boiler. The boiler feed pumps consume a large fraction of the auxiliary power used internally within a power plant. Boiler feed pumps can require power in excess of 10 MW on a 500-MW power plant. Therefore, the maintenance on these pumps should be rigorous to ensure both reliability and high-efficiency operation Boiler feed pumps wear over time and subsequently operate below the original design efficiency. The most pragmatic remedy is to rebuild a boiler feed pump in an overhaul or upgrade.
The air pre-heater is a device that recovers heat from the flue gas for use in pre-heating the incoming combustion air (and potentially for other uses such as coal drying). Properly operating air pre-heaters play a significant role in the overall efficiency of a coal-fired EGU. A major difficulty associated with the use of regenerative air pre-heaters is air leakage from the combustion air side to the flue gas side. Air leakage affects boiler efficiency due to lost heat recovery and affects the axillary load since any leakage requires additional fan capacity. The amount of air leaking past the seals tends to increase as the unit ages. Improvements to seals on regenerative air pre-heaters have enabled the reduction of air leakage.
The most precise and energy-efficient method of flue gas flow control is use of VFD. The VFD controls fan speed electrically by using a static controllable rectifier (thyristor) to control frequency and voltage and, thereby, the fan speed. The VFD enables very precise and accurate speed control with an almost instantaneous response to control signals. The VFD controller enables highly efficient fan performance at almost all percentages of flow turndown.
Due to current electricity market conditions, many units no longer operate at base-load capacity and, therefore, VFDs, also known as variable-speed drives on fans can greatly enhance plant performance at off-peak loads. Additionally, because utilities are phasing in their environmental equipment upgrades, new fans are oversized and operated at lower capacities until all additional equipment has been added. Under these scenarios, VFDs can significantly improve the unit heat rate. VFDs as motor controllers offer many substantial improvements to electric motor power requirements. The drives provide benefits such as soft starts, which reduce initial electrical load, excessive torque, and subsequent equipment wear during startups; provide precise speed control; and enable high-efficiency operation of motors at less than the maximum efficiency point. During load turndown, plant auxiliary power could
Upgrades or overhauls of steam turbines offer the greatest opportunity for HRI on many units. Significant increases in performance can be gained from turbine upgrades when plants experience problems such as steam leakages or blade erosion. The typical turbine upgrade depends on the history of the turbine itself and its overall performance. The upgrade can entail myriad improvements, all of which affect the performance and associated costs. The availability of advanced design tools, such as computational fluid dynamics (CFD), coupled with improved materials of construction and machining and fabrication capabilities have significantly enhanced the efficiency of modern turbines. These improvements in new turbines can also be utilized to improve the efficiency of older steam turbines whose efficiency has degraded over time. Upgrades or overhauls of steam turbines may offer the greatest opportunity for HRI on many units. Significant increases in performance can be gained from turbine upgrades when plants experience problems such as steam leakages or blade erosion. The typical turbine upgrade depends on the history of the turbine itself and its overall performance. The upgrade can entail myriad improvements, all of which affect the performance and associated costs.
In steam power plants, economizers are heat exchange devices used to capture waste heat from boiler flue gas which is then used to heat the boiler feedwater. This use of waste heat reduces the need to use extracted energy from the system and, therefore, improves the overall efficiency or heat rate of the unit. As with most other heat transfer devices, the performance of the economizer will degrade with time and use, and power plant representatives contend that economizer replacements are often delayed or avoided due to concerns about triggering NSR requirements. In some cases, economizer replacement projects have been undertaken concurrently with retrofit installation of selective catalytic reduction (SCR) systems because the entrance temperature for the SCR unit must be controlled to a specific range.
Many unit operators can achieve additional HRI by adopting best operating and maintenance practices. The amount of achievable HRI will vary significantly from unit to unit. In setting a standard of performance for a specific unit or subcategory of units, states should consider the opportunities for HRI from the following actions.
EGU operators can obtain HRI by adopting “awareness training” to ensure that all O&M staff are aware of best practices and how those practices affect the unit's heat rate.
Some large utilities have internal groups that can perform on-site evaluations of heat rate performance improvement opportunities. Outside (
Effective operation of the steam surface condenser in a power plant can significantly improve a unit's heat rate. In fact, in many cases it can pose the most significant hindrance to a plant trying to maintain its original design heat rate. Since the primary function of the condenser is to condense steam flowing from the last stage of the steam turbine to liquid form, it is most desirable from a thermodynamic standpoint that this occurs at the lowest temperature reasonably feasible. By lowering the condensing temperature, the backpressure on the turbine is lowered, which improves turbine performance.
As mentioned earlier, under CAA section 111(a)(1), EPA is required to determine “the best system of emission reduction which (taking into account the cost . . .) . . . has been adequately demonstrated.” In several cases, the D.C. Circuit has elaborated on this cost factor in various ways, stating that EPA may not adopt a standard for which costs would be “exorbitant,”
Any efficiency improvement made by an EGU will also reduce the amount of fuel consumed per unit of electricity output; fuel costs can account for as much as 70 percent of production costs of power. The cost attributable to CO
Most often, when evaluating costs for criteria pollutants—in a BACT analysis, for example—the emphasis is focused on the cost of control relative to the amount of pollutant removed—a metric typically referred to as the “cost-effectiveness.” There have been relatively few BACT analyses evaluating GHG reduction technologies for coal-fired EGUs; and, therefore not a large number of GHG cost-effectiveness determinations to compare against as a measure of the cost reasonableness. Nevertheless, in PSD and Title V permitting guidance for GHG emissions, EPA noted that “it is important in BACT reviews for permitting authorities to consider options that improve the overall energy efficiency of the source or modification—through technologies, processes and practices at the emitting unit. In general, a more energy efficient technology burns less fuel than a less energy efficient technology on a per unit of output basis.”
The estimated costs for the BSER candidate technologies are presented below in Table 2. These are cost ranges from the 2009 S&L Study
In the CPP, EPA estimated the potential national average net HRI by coal-fired EGUs to between 2.1 to 4.3 percent for each interconnection, or about 4 percent nationally, with the improvements coming from some combination of best operating practices and equipment upgrades. The Agency noted in the CPP that the maximum cost of HRI from Table 2 is expected to be less than the $100/kW value used in the CPP proposal, especially as the EGU size increases; and, therefore, the Agency assessed the economic effects of HRI costs that might range from $50 to $100/kW. The technical applicability and efficacy of HRI measures and the cost of implementing them are dependent upon site specific factors and can vary widely from site to site. Because there is inherent flexibility provided to the states in applying the standards of performance, there is a wide range of potential outcomes that are highly dependent upon how the standards are applied (and to what degree states take into consideration other factors, including remaining useful life).
In the RIA accompanying this proposal, the Agency evaluates three illustrative scenarios that recognize the inherent flexibility provided to states in applying standards of performance and provide insight on potential outcomes. For those illustrative scenarios, EPA evaluates costs ranging from $50/kW to $100/kW. EPA requests comment, with analysis, on other cost ranges that may be appropriate.
As directed by CAA section 111(a)(1), EPA has taken into account nonair quality health and environment requirements, and energy requirements for each of the candidate BSER technologies listed in Tables 1 and 2. None of the candidate technologies, if implemented at a coal-fired EGU, would be expected to result in any deleterious effects on any of the liquid effluents (
Implementation of heat rate improvement measures also would achieve reasonable reductions in CO
Government agencies and laboratories, industry research organizations, engineering firms, equipment suppliers, and environmental organizations have conducted studies examining the potential for improving heat rate in the U.S. EGU fleet or a subset of the fleet. Table 3 below provides a list of some reports, case studies, and analyses about HRI opportunities in the United States. EPA is seeking comment on how these studies (and any others that the Agency should be aware of) can inform our understanding of potential HRI opportunities (Comment C-8).
It has been noted that unit-level HRIs, with the resulting reductions in variable operating costs at those improved EGUs, could lead to increases in utilization of those EGUs as compared to other generating options (
As part of the cost-benefit analysis in the RIA for this proposed action, EPA modeled a range of potential HRIs (percent improvement, as described in the RIA). The results of the modeling, for the years of analysis for this rule, predict that there will be no cumulative increases in system-wide emissions relative to a scenario where no action is taken. While the RIA shows that, under certain assumptions, sources that adopt HRI may increase generation, due to their improved efficiency and relatively improved economic competitiveness, they also generally reduce emissions (as a group) because they can generate higher levels of electricity with a lower overall emission rate. Hence, EPA analysis indicates that the system-wide emission decreases due to reduced heat rate are likely to be larger than any system-wide increases due to increased operation. EPA solicits comment on this conclusion (Comment C-9).
EPA has also considered opportunities for emission reductions at natural gas-fired stationary combustion turbines as a part of the BSER—at both simple cycle turbines and combined cycle turbines—and previously determined that the available emission reductions would likely be expensive or would likely provide only small overall reductions relative to those that were predicted through application of other systems of emission reduction identified in the CPP building blocks. In the development of the CAA section 111(b) standards of performance for new, modified, and reconstructed EGUs, several commenters provided information on options that may be available to improve the efficiency of existing natural gas-fired stationary combustion turbines.
In addition to upgrades to the combustion turbine, the operator of a NGCC unit may have the opportunity to improve the efficiency of the heat recovery steam generator and steam cycle using retrofit technologies that may reduce the GHG emissions by 1.5 to 3 percent. These include: (1) Steam path upgrades that can minimize aerodynamic and steam leakage losses; (2) replacement of the existing high-pressure turbine stages with state-of-the-art stages capable of extracting more energy from the same steam supply; and (3) replacement of low-pressure turbine stages with larger diameter components that extract additional energy and that reduce velocities, wear, and corrosion.
In the ANPRM, EPA requested comment on the broad availability and applicability of any HRIs for natural gas combustion turbine EGUs. EPA also solicited comment on the Agency's previous determination in the CPP that the available GHG emission reduction opportunities would likely provide only small overall GHG reductions as compared to those from HRIs at existing coal-fired EGUs.
Several commenters suggested that there are significant opportunities for emission reductions via HRIs at natural gas combined cycle EGUs while many other commenters contended that any such emission reductions would be minimal and too expensive. Still, other commenters noted that operational changes—such as lower capacity factor or fluctuations in load (cycling)—affect the heat rate and make it difficult to accurately gauge the availability of HRI opportunities for NGCC EGUs.
However, while numerous comments suggested that there are available HRI opportunities at existing NGCC EGUs, no commenters provided specific information on the availability, applicability, or cost of HRI opportunities for NGCC units—nor did any commenters provide any information on the magnitude of expected heat rate reductions.
To assess potential HRI of existing NGCC EGUs, EPA looked at 11 years of historical gross heat rate data from 2007 to 2017 for existing NGCC EGUs that reported both heat input and gross electricity output to the Agency in 2017. The Agency used the 2007 to 2016 data to calculate a “benchmark” heat rate for each unit. EPA evaluated the HRI potential using an approach that is similar to the method used to determine a unit-specific standard that was finalized for modified coal-fired EGUs. The Agency evaluated the HRI potential by comparing the 2017 national annual heat rate with the best annual heat rate in the years from 2007 to 2016 year. The HRI potential was calculated nationally and at each regional interconnection: East, West, and Texas. Nationally the HRI evaluation suggested an average HRI potential of 3.4 percent.
EPA also conducted a literature search and found some papers suggesting potential for improvement in the heat rate. The literature suggested that most HRIs would be accompanied by commensurate capacity increases.
EPA also considered other systems of GHG emission reductions that may be applied to affected EGUs but is not proposing that they should be part of the BSER for the reasons discussed below. EPA acknowledges that there may be other methods and technologies suitable for adoption at some specific sources, but states and sources are best suited to determine if those alternative measures and technologies are appropriate and/or allowable compliance measures.
EPA has
Similarly, EPA considered whether CCS or partial CCS should be the BSER for natural gas-fired stationary combustion turbines and have determined that, currently, the technology is exorbitantly expensive, has not been adequately demonstrated, and would not be available for a large number of existing sources. Similar technologies—such as use of the novel Allam Cycle
EPA has previously determined that co-firing of alternative fuels (biomass or natural gas) in coal-fired utility boilers is not part of BSER for existing fossil fuel-fired sources due to cost and feasibility considerations.
Coal-fired power plants typically use natural gas or other clean fuel (such as low sulfur fuel oil) for start-up operations and, if needed, to maintain the unit in “warm stand-by.” Some plants co-fire natural gas simultaneously with coal—either directly as a combustion fuel or in configuration referred to as natural gas reburn, which is used for NOx control. During periods of natural gas co-firing, an EGU's CO
In evaluating BSER technology options, CAA section 111(a)(1) directs EPA to take into account nonair quality health and environmental impacts, and energy requirements. EPA is unaware of any significant nonair quality health or environmental impacts associated with natural gas co-firing. However, in taking energy requirements into account, EPA notes that co-firing natural gas in coal-fired utility boilers is not the best, most efficient use of natural gas and, as noted above, can lead to inefficient operation of utility boilers. NGCC stationary combustion turbine units are much more efficient at using natural gas as a fuel for the production of electricity and it would not be an environmentally positive outcome for utilities and owner/operators to redirect natural gas from the more efficient NGCC EGUs to the less efficient coal-fired EGUs in order to satisfy an emission standard at the coal-fired unit.
Moreover, unlike coal, natural gas cannot be stored in quantities sufficient for sustained utilization on site. Accordingly, delivery of natural gas via pipeline is essential for using natural gas at coal-fired EGUs. Many existing coal-fired plants, however, do not have access to natural gas transportation infrastructure and gaining access would be either infeasible (due to technical or timing considerations) or unreasonably costly.
The infrastructure, proximity and cost aspects of co-firing biomass at existing coal EGUs are similar in nature and concept to those of natural gas. While there are some existing coal-fired EGUs that currently co-fire with biomass fuel, those are in relatively close proximity to cost-effective biomass supplies; and, there are regional supply and demand dynamics at play. As with the other emission reduction measures discussed in this section, EPA expects that use of some types of biomass may be economically attractive for certain individual sources. However, on a broader scale, biomass co-firing is more expensive and/or less achievable than the measures determined to be part of the BSER. As such, EPA is not proposing that the use of biomass fuels is part of the BSER because too few individual sources will be able to employ that measure in a cost-reasonable manner.
As discussed in Section III above, EPA has the authority to determine the BSER as part of regulations it promulgates pursuant to CAA section 111(d)(1) (providing that states shall submit plans to EPA establishing “standards of performance” for existing sources);
EPA expects that states can use the information that EPA provides on the degree of emission limitation in developing standards of performance for affected EGUs as part of establishing a standard of performance for inclusion in a state's plan pursuant to the requirements of section 111(d)(1). In this case, the ranges of HRIs are provided as guidance for states to use in evaluating the efficacy of implementing each measure identified as part of the BSER candidate technologies at each affected EGU. While the HRI potential range is provided as guidance for the states, the actual HRI performance for each of the candidate technologies will be unit-specific and will depend upon a range of unit-specific factors. The states will use the information provided by EPA as guidance, but will be expected to conduct unit-specific evaluations of HRI potential, technical feasibility, and applicability for each of the BSER candidate technologies. Once a state evaluates the HRIs identified as part of the BSER in establishing a standard of performance for a particular affected EGU, it is within the state's discretion to take certain factors concerning that source, such as remaining useful life, into consideration when determining how the standard of performance should be applied. The next section describes how states may derive a standard of performance reflecting the degree of emission limitation achievable through application of the BSER.
Additionally, the new proposed implementing regulations require that an emission guideline identify information such as a timeline for compliance with standards of performance that reflect the application of the BSER.
EPA is proposing, consistent with the new proposed implementing regulations (subpart Ba), that states will include custom compliance schedules for affected EGUs as part of their state plan. This is another area that states have latitude for taking into account unit specific factors. It should be noted however, that per the proposed new implementing regulations, if a state chooses to include a compliance schedule for a source that extends more than twenty-four months from the submittal of the state plan, the plan must also include legally enforceable increments of progress for that source (
As described in other parts of this section, while EPA's role is to determine the BSER, section 111(d)(1) squarely places the responsibility of establishing a standard of performance for an existing source on the state as part of developing a state plan. EPA is proposing that once EPA determines the BSER, states are expected to evaluate each of the BSER HRI measures that EPA has determined represent BSER in establishing a standard of performance for each source within their jurisdiction. The states, in applying the standards of performance, may take into consideration, among other factors, the remaining useful life of the existing source to which the standard would apply (see Section VI.B.1 for further discussion on remaining useful life and other factors). The proposed BSER is a list of candidate technologies that are HRI measures, which states should evaluate, and potentially apply to existing sources as appropriate based upon the specific characteristics of those units. In general, EPA envisions that, under the proposed program, the states would set standards based on considerations most appropriate to individual sources or groups of sources (
Several commenters on the ANPRM suggested that EPA should develop a default methodology for determining appropriate standards of performance that are consistent with the BSER. More specifically, commenters suggested that EPA should use a methodology that is similar to the one finalized for major modifications at coal-fired EGUs under the section 111(b) program—
As mentioned earlier, states may take into consideration other factors, including remaining useful life, when applying unit-specific standards of performance. Consideration of these factors may result in the application of the standard of performance in a less stringent manner than would otherwise be suggested by strict implementation of the BSER technologies. This topic is discussed in detail in Section VI.B.
As previously described, this proposal seeks to clarify the Agency's and states' roles under section 111(d). The statute is clear that EPA determines the BSER, and states submit plans that establish standards of performance for existing sources that, under the definition of “standard of performance in CAA section 111(a)(1), reflect the degree of emission limitation achievable though the application of the BSER. Consistent with the statute, EPA's proposed implementing regulations at 40 CFR 60.22a(b)(2) specify that an emission guideline must include
Given that section 111(d)(1) requires states to submit plans that establish standards of performance for affected sources, EPA believes it is consistent with the spirit of cooperative federalism to provide information sufficient to assist states in the development of state plans, which in turn will provide both states and sources with regulatory certainty via a plan that is approvable under section 111(d)(2) and applicable regulations. As mentioned above, EPA is proposing to provide information regarding ranges of expected reductions associated with the various HRIs identified as the BSER, which will assist states in establishing appropriate standards of performance for affected EGUs. EPA proposes to determine providing such information is consistent with both the implementing regulations at 40 CFR 60.22(b) and CAA section 111(d) regarding the roles of states and EPA determining the degree of emission limitation achievable through application of the BSER.
As described below in Section VI.B, under the statute, the proposed new implementing regulations, and these proposed emission guidelines, states have considerable flexibility in developing their plans and establishing and applying standards of performance to existing sources. One of the areas of flexibility described is in the standard setting process for EGUs. As part of this flexibility, EPA is proposing that states should have broad flexibility on whether and how the state chooses to group, sort, or subcategorize affected EGUs within the state to establish standards of performance. In evaluating affected EGUs, if a state finds that there is an overlap in circumstances around a group of EGUs, it might make sense to implement a uniform methodology for setting a standard of performance across that group. Another area of flexibility is explicitly provided in the statutory text of 111(d)(1) itself. The statute requires that EPA's regulations implementing section 111(d) shall permit the State in applying a standard of performance to any particular source under a plan submitted under this paragraph to take into consideration, among other factors, the remaining useful life of the existing source to which such standard applies.
As described further in Section VII.C of this preamble, EPA is proposing a new implementing regulation for section 111(d) which includes a proposed definition of “standard of performance that aligns with the statutory definition of the term under CAA section 111(a)(1). EPA is further proposing, as part of the new implementing regulations, that a specific emission guideline may contain provisions that supersede the applicability of the implementing regulations. In the context of these emission guidelines, EPA is proposing that an allowable emission rate (
EPA is proposing an allowable emission rate of CO
EPA also requests comment on the merits of differentiating between gross and net heat rate (Comment C-16). This may be particularly important when considering the effects of part load operations (
Once EPA determines the BSER, section 111(d)(1) of the CAA requires that “each State shall submit to the Administrator a plan which (A) establishes standards of performance for any existing source [. . .], and (B) provides for the implementation and enforcement of such standards of performance.” Section 111(d)(1) further requires EPA to “permit the State in applying a standard of performance to any particular source under a plan [. . .] to take into consideration, among other factors, the remaining useful life of the existing source to which such standard applies.”
In light of the cooperative-federalist structure of section 111(d) and its express language requiring that EPA allow states to take into account source-specific factors when establishing standards of performance for existing sources, EPA believes it is appropriate in this proposal to provide considerable flexibility for states to set standards of performance for units and also allow states to have considerable latitude for implementing measures and standards for affected EGUs. A detailed discussion of the flexibility that states have in developing standards of performance is provided below in Section VI.B.1. States also have flexibility in the measures and processes that they put in place for affected EGUs to meet their compliance obligations. One of the examples of this is discussed in Section VI.B.2 on averaging and trading. As previously discussed, the BSER's candidate technologies affords states considerable flexibility to determine how to apply standards of performance to affected sources. Several commenters noted in the ANPRM that flexibility for States and affected sources should be part of any replacement rule, with States being able to choose from a wide variety of possible methods for developing a standard of performance, along with options for how to implement the standard through their state plans. Other commenters suggested that any flexible compliance opportunities provided should be directly linked to the determination of the BSER, such that increased compliance flexibility in the state's establishment of a standard of performance for an existing source can only be included to the extent that the flexibility is included as part of the BSER.
Another important and distinctly different element of flexibility in this proposal is the availability of compliance options for affected sources in meeting their standards of performance. To the extent that a state develops a standard of performance for an affected source within its jurisdiction, the state is free to give the source flexibility to meet that standard of performance using either BSER technologies or some other non-BSER technology or strategy. In other words, an affected source may have broad discretion in meeting its standard of performance within the requirements of a state's plan. For example, there are technologies, methods, and/or fuels that can be adopted at the affected source to allow the source to comply with its standard of performance that were not determined to be the BSER, but which may be applicable and prudent for specific units to use to meet their compliance obligations. Examples of non-BSER technologies and fuels include HRI technologies that were not included as candidate technologies, CCS, and fuel co-firing (natural gas or certain biomass). In keeping with past programs that regulated affected sources using a standard of performance, EPA takes no position regarding whether there may be other methods or approaches to meeting such a standard, since there are likely various approaches to meeting the standard of performance that EPA is either unable to include as part of the BSER, or is unable to predict. EPA proposes that affected sources may use both BSER and non-BSER measures to achieve compliance with their state plan obligations.
To demonstrate that measures taken to meet compliance obligations for a source actually reduce its emission rate, EPA proposes that the measures should meet two criteria: (1) They are implemented at the source itself, and (2) they are measurable at the source of emissions using data, emissions monitoring equipment or other methods to demonstrate compliance, such that they can be easily monitored, reported and verified at a unit. There may be other technologies or compliance measures that meet these general criteria. EPA solicits comment on whether these two criteria are appropriate or not and why, and whether there may be compliance flexibilities that might meet the two proposed criteria (Comment C-17). This proposed rule is intended to generally allow compliance flexibility in state plans where appropriate, to the extent they contribute to meeting any particular standard of performance, consistent with the criteria. EPA is further soliciting comment on whether there are certain non-BSER measures that should be disallowed for compliance, and if so, under what criteria or rationale should measures be disallowed for compliance (Comment C-18).
Section 111(d)(1)(B) additionally requires state plans to include measures that provide for the implementation and enforcement of standards of performance. EPA believes states can meet these requirements by including measures as described in Section VI.C of this proposal regarding state plan components, such as monitoring, reporting, and recordkeeping requirements. EPA solicits comments on what other implementation and enforcement measures may be necessary for states to meet the requirements of section 111(d)(1)(B) (Comment C-19). Additionally, as part of ensuring that regulatory obligations appropriately meet statutory requirements such as enforceability, EPA has historically and consistently required that obligations placed on sources be quantifiable, non-duplicative, permanent, verifiable, and enforceable. EPA is similarly proposing that standards of performance places on affected EGUs as part of a state plan be quantifiable, non-duplicative, permanent, verifiable, and enforceable.
The Agency specifically recognizes that some entities may be interested in using biomass as a compliance option for meeting the state determined emission standard.
Certain kinds of biomass, including that from managed forests, have the potential to offer a wide range of economic and environmental benefits, including carbon benefits. However, these benefits can typically only be realized if biomass feedstocks are sourced responsibly, which can include ensuring that forest biomass is not sourced from lands converted to non-forest uses. States that intend to propose the use of forest-derived biomass for compliance by affected units may refer to EPA's April 2018 statement on its intended treatment of biogenic CO
EPA solicits comments on the inclusion of forest-derived biomass as a compliance option for affected units to meet state plan standards under this rule (Comment C-20). The Agency also solicits comment on the inclusion of non-forest biomass (
Section 111(d)(1) requires that EPA's regulations must permit states to take into account, among other factors, an affected source's remaining useful life when establishing an appropriate standard of performance. In other words, Congress explicitly envisioned under section 111(d)(1) that states could implement standards of performance that vary from EPA's emission guidelines under appropriate circumstances.
Congress explicitly mentions consideration of remaining useful life in 111(d). Ultimately remaining useful life impacts cost. When EPA develops a BSER, EPA typically considers factors such as cost relative to assumptions about a typical unit. If the remaining useful life of a particular unit is less, that will generally increase the cost of control because the time to amortize capital costs is less. When congress mentions other factors, EPA believes that these are generally other factors that may substantially increase costs relative to a more typical unit.
As such, EPA is proposing, as part of the proposed implementing regulations, to permit states to take into account remaining useful life, among other factors, in establishing a standard of performance for a particular affected source, consistent with section 111(d)(1)(B). EPA solicits comments on the manner in which states should be permitted to exercise their statutory authority to take into account remaining useful life and on what “other factors” might appropriately be besides remaining useful life (Comment C-22). As described in Section VII.F., EPA further proposes as part of the new implementing regulations that the following factors give meaning to section 111(d)(1)(B):
• Unreasonable cost of control resulting from plant age, location, or basic process design;
• Physical impossibility of installing necessary control equipment; or
Other factors specific to the facility (or class of facilities) that make application of a less stringent standard or final compliance time significantly more reasonable. Given that there are unique attributes and aspects of each affected source, there are important factors that influence decisions to invest in technologies to meet a potential performance standard. These include timing considerations like expected life of the source, payback period for investments, the timing of regulatory requirements, and other unit-specific criteria. The state may find that there are space or other physical barriers to implementing certain HRIs at specific units. Or the state may find that some heat rate improvement options are either not applicable or have already been implemented at certain units. EPA understands that many of these “other factors” that can affect the application of the BSER candidate technologies distill down to a consideration of cost. Applying a specific candidate technology at an affected EGU can be a unit-by-unit determination that weighs the value of both the cost of installation and the CO
As previously described, EPA proposes that states that utilize the proposed variance provision in the new implementing regulations to establish a less stringent standard of performance for an affected EGU and/or a compliance schedule that is longer than that contemplated in EPA's final emission guideline must demonstrate as part of their state plan submission that such application of the provision meets the criteria described in the factors in Section VII.D. EPA also recognizes that for some sources, the criteria may result in determining that no measures in the candidate technologies are applicable. Two examples of this might be a unit with a very short remaining useful life or a unit that has already implemented all of the candidate technologies of the BSER. In cases such as these, a state should still establish a standard of performance. In the case of a unit with a short remaining useful life, EPA takes comment on what such a standard might look like (Comment C-24). For instance, a state could set a standard using both an emission rate and a compliance deadline to address this instance. The emission standard would only be applicable if a source did not shut down by the compliance deadline. In the case of an affected EGU that has already implemented all of the candidate technologies, EPA would expect that a state set a standard of performance that would reflect an emission rate that is at least as stringent as “business as usual” for that source without allowing for any backsliding on performance. EPA requests comment on these proposed treatments of a source that either has a short remaining useful
EPA is also generally soliciting comment on whether there are considerations in allowing states to utilize this proposed variance provision in the new implementing regulations in response to the final emission guideline, including the potential interaction of the compliance flexibilities proposed in this proposal with utilization of the provision (Comment C-25). For example, could states authorize trading as a compliance mechanism for affected EGUs and additionally invoke this provision, or would utilizing both trading and this provision in establishing standards in a state plan potentially result in such standards going beyond what section 111(d) permits (
Another consideration for states in determining a standard of performance with consideration to unique aspects at an affected EGU is the interaction between BSER and NSR. EPA is aware that the prospect of triggering NSR, and its associated permitting requirements, may have discouraged sources from implementing some heat rate improvements previously. In Section VIII of this preamble, EPA discusses proposed changes to alleviate NSR burdens for EGUs undertaking heat rate improvements. The proposed action on NSR would ultimately impact the level of reductions reflected in the standard of performance that a state establishes for its sources. In considering each of the candidate technologies, EPA believes it is appropriate for states to consider the potential that the application of HRI may trigger NSR for some sources, and associated NSR requirements could ultimately impact the cost of HRI and the way the state applies standards to an affected EGU. EPA solicits comment on any factors that may play a role in a state setting a standard of performance with consideration to NSR (Comment C-27).
EPA solicits comment on the question of whether CAA section 111(d) authorizes states to include averaging and trading between existing sources in the plans they submit to meet the requirements of a final emission guideline (Comment C-28). Section 111(d)(1) provides that states shall submit a plan which (A) establishes standards of performance for any existing source of certain air pollutants to which a 111(b) standard would apply if they were new sources, and (B) provides for the implementation and enforcement of such standards of performance. EPA's regulations under section 111(d) must permit the state, in applying a standard of performance to any particular existing source under a state plan, to consider, among other factors, the remaining useful life of that source.
To be clear, this section discusses averaging in the context of averaging across a facility and across multiple existing sources. For a discussion on EPA allowing individual EGU emissions averaging over a period of time, see Section VI.C.
EPA is proposing to allow states to incorporate, as a part of their plan, emissions averaging among EGUs across a single facility. The Agency's determination of the BSER is predicated on measures that can be implemented at the facility level and averaging across a facility is consistent with the proposed BSER. EPA is proposing that averaging at a facility only be applicable to affected EGUs (
Notwithstanding EPA's discussion above, EPA believes that there are both legal and practical concerns may weigh against the inclusion of averaging and trading between existing sources in state plans at any level more broad than averaging between sources across a particular facility. First, EPA is concerned that averaging and trading across affected sources (or between affected sources and non-affected sources,
Second, EPA believes that if section 111(d) authorized states to include trading and averaging between sources in their plans, the express provision under 111(d)(1) authorizing states to consider existing sources' remaining useful life and other factors when establishing and applying standards of performance could be viewed as superfluous. Once a state takes into consideration a source's remaining useful life and other factors (
Third, multiple practical concerns regarding emissions averaging and trading between sources inform EPA's concerns regarding inclusion of those mechanisms in state plans under section 111(d) and its solicitation of comment on this issue. These concerns include the relative complexity of development and implementation of a state plan that includes averaging or trading, as well as the difficulty in ensuring robust compliance with standards of performance by means of averaging or trading. Trading programs necessitate developing adequate means of evaluation, monitoring, and verification (EM&V) to ensure that standards of performance are actually complied with, and these programmatic aspects increase the burden on states in developing a satisfactory state plan, and on sources in demonstrating compliance. Additionally, either a mass-based or rate-based trading program potentially brings into question of whether the state has established standards of performance that appropriately reflect the BSER. Under a trading program, a single source could potentially shut down or reduce utilization to such an extent that its reduced or eliminated operation generates adequate compliance instruments for a state's remaining sources to meet their standards of performance without implementing any additional measures at any other source. This compliance strategy might undermine EPA's BSER, which EPA is proposing to determine as a menu of heat rate improvements. It would also undermine the purpose of section 111 in a broader sense. The section is directed toward the
However, EPA recognizes that there are significant benefits of averaging and trading across affected sources and is interested in whether emissions averaging could be a way to provide flexibility while still focusing on a core tenet of the BSER for this rule: Reducing emissions per MWH of coal-fired generation. Since averaging traditionally focuses only on the emission rate during hours of operation, it focuses on encouraging lowering emissions per MW generated and not on encouraging generation shifting away from the affected source category. The EPA welcomes comment on whether there is a way to allow trading between affected EGUs across affected sources while not encouraging generation shifting (Comment C-31).
EPA is soliciting comment on whether section 111(d) should be read not to authorize states to include trading and averaging between sources, EPA is also interested in affording flexibility to states and sources in meeting their respective obligations and solicits public comment on whether this proposed interpretation and conclusion is compatible with that goal. EPA is primarily interested in comments pertaining to whether averaging could and should be allowed for trading, and to what degree (
Section 111(d)(1) of the Clean Air Act requires that in addition to establishing standards of performance for affected sources, such plans must also provide for the implementation and enforcement of such standards. As described in Section VII, EPA is proposing new implementing regulations for section 111(d), which in part carry over a number of the same provisions currently present in the existing implementing regulations under 40 CFR part 60, subpart B. EPA is proposing that these provisions apply for states to meet the requirement that state plans include implementation and enforcement measures. EPA requests comment on whether these provisions are appropriate to apply for purposes of meeting obligations under a final rule in response to this proposal, or whether other implementation or enforcement measures should be required (Comment C-42).
Additionally, EPA is proposing that states must include appropriate monitoring, reporting, and recordkeeping requirements to ensure that state plans adequately provide for the implementation and enforcement of standards of performance. Each state will have the flexibility to design a
EPA also notes that states have it within their discretion to establish averaging times for affected EGUs. Averaging the emission rate of an affected EGU over different time periods may have different effects on the demonstration of compliance for an EGU to the state. EPA solicits comment on whether there should be any bounds or consideration to the averaging times that states are allowed to consider (Comment C-43).
EPA is further proposing to apply generally the proposed new implementing regulations for timing, process and required components for state plan submissions and implementation for state plans required under for affected EGUs. The new implementing regulations are described in detail in Section VII. In addition to application of the implementing regulations to state plans in response to a final emission guideline under this proposal, EPA is also proposing that state plans be comprehensively submitted electronically through an EPA provided platform. EPA solicits comment on whether electronic submittals are appropriate and less burdensome to states (Comment C-44) and whether this should be the sole means of submitting state plans (Comment C-45). EPA believes that electronic submittals will ease the burden of state plan submittals for both states and EPA.
In section 60.5740a of the regulatory text for this proposal, there is description and list of what a state plan must include. EPA solicits comment on whether this list is comprehensive to submit a state plan (Comment C-46).
Distinct from EPA's proposed emission guidelines for the regulation of GHGs for existing affected EGUs, EPA is also proposing to promulgate new regulations to implement section 111(d) regulations. As previously described, the current implementing regulations at 40 CFR part 60, subpart B were promulgated in 1975 [
EPA is proposing to largely carry over the current implementing regulations in 40 CFR part 60, subpart B to a new subpart that will be applicable to EPA's emission guidelines and state plans or federal plans associated with such emission guidelines, both those contemplated in this proposal and for any others that may be published or promulgated either concurrently or subsequent to final promulgation of the new implementing regulations. For purposes of regulatory certainty, EPA believes it is appropriate to apply these new implementing regulations prospectively, and retain the existing implementing regulations as applicable to section 111(d) emission guidelines and associated state plans that were promulgated previously. Additionally, the existing implementing regulations at 40 CFR part 60, subpart B are applicable to regulations promulgated under CAA section 129, and associated state plans. EPA intends to retain the applicability of the existing implementing regulations with respect to rules and state plans associated with section 129, and the proposed new implementing regulations are intended to apply only to section 111(d) regulations and associated state plans issued solely under the authority of section 111(d). EPA requests comments on this proposed applicability of both the existing and new implementing regulations (Comment C-47).
EPA is aware that there are a number of cases where state plan submittal and review processes are still ongoing for existing 111(d) emission guidelines. Because EPA is proposing changes to the timing requirements to more closely align 111(d) with both general SIP submittal timing requirements and because of the realities of how long these actions take, EPA is proposing to apply the changes to timing requirements to both emission guidelines published after the new implementing regulations are finalized, and to all ongoing emission guidelines already published under section 111(d). EPA is soliciting comment on the proposed timing requirements for prospective emission guidelines under the new implementing regulations and the alignment of ongoing emission guidelines by amending their respective regulatory text to incorporate the new timing requirements. (Comment C-48). EPA is proposing to apply the timing changes to all ongoing 111(d) regulations for the same reasons that EPA is changing the timing requirements prospectively. Based on years of experience with working with states to develop SIPs under section 110, EPA believes that given the comparable amount of work, effort, coordination with sources, and the time required to develop state plans that more time is necessary for the process. Giving states three years to develop state plans is more appropriate than the nine months provided for under the existing implementing regulations considering the workload. These practical considerations regarding the time needed for state plan development are also applicable and true for recent emission guidelines where the state plan submittal and review process are still ongoing.
For those provisions that are being carried over from the existing implementing regulations into the new implementing regulations, EPA believes the placement of those provisions under a new subpart is a ministerial action that does not require reopening the substance of those provisions for notice and comment. EPA is not intending to substantively change those provisions from their original promulgation, and continues to rely on the record under
EPA is also sensitive to potential confusion over whether these new implementing regulations would apply to an emission guideline previously promulgated or to state plans associated with a prior emission guideline, so EPA is proposing that the new implementing regulations are applicable only to emission guidelines and associated plans developed after promulgation of this regulation, including the emission guideline being proposed as part of this action for GHGs and existing affected EGUs. EPA solicits comment on this proposed applicability of the new implementing regulations (Comment C-49).
While EPA is carrying over a number of requirements from the existing implementing regulations, EPA is proposing specific changes to better align the regulations with the statute. These changes are reflected in the proposed regulatory text for this action, and EPA solicits comments on both the substance of these changes and the proposed regulatory text (Comment C-50). These changes include:
• An explicit provision allowing a specific emission guideline to supersede the requirements of the new implementing regulations;
• Changes to the definition of “emission guideline”;
• Updated timing requirements for the submission of state plans;
• Updated timing requirements for EPA's action on state plans;
• Updated timing requirements for EPA's promulgation of a federal plan;
• Updated timing requirement for when increments of progress must be included as part of a state plan;
• Completeness criteria and a process for determining completeness of state plan submissions similar to CAA section 110(k)(1) and (2);
• Updated definition replacing “emission standard” with “standard of performance;”
• Usage of the internet to satisfy certain public hearing requirements;
• No longer making a distinction between public health-based and welfare-based pollutants in an emission guideline; and,
• Updating the variance provision to be consistent with CAA section 111(d)(1)(B).
EPA is proposing to include a provision in the new implementing regulations that expressly allows for any emission guideline to supersede the applicability of the implementing regulations as appropriate. EPA cannot foresee all of the unique circumstances and factors associated with a particular future emission guideline, and therefore different requirements may be necessary for a particular 111(d) rulemaking that EPA cannot envision at this time. The proposed provision is parallel to one contained in the 40 CFR part 63 General Provisions implementing section 112 of the CAA. EPA solicits comments on the inclusion of such provision as part of the implementing regulations for section 111(d) (Comment C-51).
Because EPA is updating the implementing regulations and many of the provisions from the existing implementing regulations are being carried over, EPA wants to be clear and transparent with regard to the changes that are being made to the implementing regulations. As such, EPA is providing Table 4 that summarizes the changes being made. EPA also has included in the docket for this action a red-line-strike-out of the changes that are being proposed.
The existing implementation regulations under 40 CFR 60.21(e) contain a definition of “emission guideline”, defining it as a guideline which reflects the degree of emission reduction achievable through the application of the best system of emission reduction which (taking into account the cost of such reduction) the Administrator has determined has been adequately demonstrated for designated facilities. This definition additionally references that an emission guideline may be set forth in 40 CFR part 60, subpart C or a “final guideline document” published under 40 CFR 60.22(a). While the implementing regulations do not define the term “final guideline document,” 40 CFR 60.22 generally contains a number of requirements pertaining to the contents of guideline documents, which are intended to provide information for the development of state plans.
The timing requirements in the existing implementing regulations for state plan submissions, EPA's action on state plan submissions and EPA's promulgation of federal plans generally track the timing requirements for SIPs and federal implementation plans (FIPs) under the 1970 version of the Clean Air Act. Congress revised these SIP/FIP timing requirements in section 110 as part of the 1990 Clean Air Act amendments. EPA proposes to accordingly update the timing requirements regarding state and federal plans under section 111(d) to be consistent with the current timing requirements for SIPs and FIPs under section 110. The existing implementing regulations at 40 CFR 60.23(a)(1) requires state plans to be submitted to EPA within nine months after publication of a final emission guideline, unless otherwise specified in an emission guideline. EPA is proposing, as part of new implementing regulations, to provide states with three years after the notice of the availability of the final emission guideline to adopt and submit a state plan to EPA. Because of the amount of work, effort, and time required for developing state plans that include unit-specific standards, and implementation and enforcement measures for such standards, EPA believes that extending the submission date of state plans from nine months to three years is appropriate. Because states have considerable flexibility in implementing section 111(d), this timing also allows states to interact and work with the Agency in the development of state plan and minimize the chances of unexpected issues arising that could slow down eventual approval of state plans. EPA solicits comment on generally providing states with three years after the publication of the final emission guidelines, and solicits comment on any other timeframes that may be appropriate for submission of state plans given the flexibilities EPA intends to provide through its emission guidelines (Comment C-52). EPA also proposes to give itself discretion to determine in a specific emission guideline that a shorter time period for the submission of state plans particular to that emission guideline is appropriate. Such authority is consistent with CAA section 110(a)(1)'s grant of authority to the Administrator to determine that a period shorter than three years is appropriate for the submission of particular SIPs implementing the NAAQS.
Following submission of state plans, EPA will review plan submittals to determine whether they are “satisfactory” as per CAA section 111(d)(2)(A). Given the flexibilities section 111(d) and emission guidelines generally accord to states, and EPA's prior experience on reviewing and acting on SIPs under section 110, EPA is proposing to extend the period for EPA review and approval or disapproval of plans from the four-month period provided in EPA implementing regulations to a twelve-month period after a determination of completeness (either affirmatively by EPA or by operation of law, see below for EPA's proposal on completeness) as part of the new implanting regulations. This timeline will provide adequate time for EPA to review plans and follow notice-and-comment rulemaking procedures to ensure an opportunity for public comment on EPA's proposed action on a state plan. EPA solicits comment on extending the timing of EPA's action on a state plan from 4 months of when a plan is due to 12 months from determination that a state plan submission is complete (Comment C-53).
EPA additionally proposes to extend the timing from six months in the existing implementing regulations to two years, as part of new implementing regulations, for EPA to promulgate a federal plan for states that fail to submit an approvable state plan in response to a final emission guideline. This two-year timeline is consistent with the FIP deadline under section 110(c) of the CAA. EPA solicits comment on change in timing for EPA to promulgate a federal plan from six months to two years (Comment C-54). EPA solicits comment on extending deadline for promulgating a final (
The existing implementing regulations require that any compliance schedule for state plans extending more than 12 months from the date required for submittal of the plan must include legally enforceable increments of progress to achieve compliance for each designated facility or category of facilities. 40 CFR 60.24(e)(1). However, as described in section VII.B, the EPA is proposing certain updates to the timing requirements for the submission of, and action on, state plans. Consequently, it follows that the requirement for increments of progress should also be updated in order to align with the proposed new timelines. Given that the EPA is proposing a period of up to 18 months for its action on state plans (
Similar to requirements regarding determinations of completeness under section 110(k)(1), EPA is proposing completeness criteria that provide the Agency with a means to determine whether a state plan submission includes the minimum elements necessary for EPA to act on the submission. EPA would determine completeness simply by comparing the state's submission against these completeness criteria. In the case of SIPs under CAA section 110(k)(1), EPA promulgated completeness criteria in 1990 at Appendix V to 40 CFR part 51 (55 FR 5830; February 16, 1990). EPA proposes to adopt criteria similar to the criteria set out at section 2.0 of Appendix V for determining the completeness of submissions under CAA section 111(d).
EPA notes that the addition of completeness criteria in the framework regulations does not alter any of the submission requirements states already have under any applicable emission guideline. The completeness criteria proposed by this action are those that would generally apply to all plan submissions under section 111(d), but specific emission guidelines may supplement these general criteria with additional requirements.
The completeness criteria that EPA is proposing in this action can be grouped into administrative materials and technical support. For administrative materials, the completeness criteria mirror criteria for SIP submissions because the two programs have similar administrative processes. Under these criteria, the submittal must include the following:
(1) A formal letter of submittal from the Governor or the Governor's designee requesting EPA approval of the plan or revision thereof.
(2) Evidence that the state has adopted the plan in the state code or body of regulations. That evidence must include the date of adoption or final issuance as well as the effective date of the plan, if different from the adoption/issuance date.
(3) Evidence that the state has the necessary legal authority under state law to adopt and implement the plan.
(4) A copy of the official state regulation(s) or document(s) submitted for approval and incorporated by reference into the plan, signed, stamped and dated by the appropriate state official indicating that they are fully adopted and enforceable by the state. The effective date of the regulation or document must, whenever possible, be indicated in the document itself. The state's electronic copy must be an exact duplicate of the hard copy. For revisions to the approved plan, the submission must indicate the changes made to the approved plan by redline/strikethrough.
(5) Evidence that the state followed all of the procedural requirements of the state's laws and constitution in conducting and completing the adoption/issuance of the plan.
(6) Evidence that public notice was given of the plan or plan revisions with procedures consistent with the requirements of 40 CFR 60.23, including the date of publication of such notice.
(7) Certification that public hearing(s) were held in accordance with the information provided in the public notice and the state's laws and constitution, if applicable and consistent with the public hearing requirements in 40 CFR 60.23.
(8) Compilation of public comments and the state's response thereto.
The technical support required for all plans must include each of the following:
(1) Description of the plan approach and geographic scope.
(2) Identification of each designated facility; identification of emission standards for each designated facility; and monitoring, recordkeeping, and reporting requirements that will determine compliance by each designated facility.
(3) Identification of compliance schedules and/or increments of progress.
(4) Demonstration that the state plan submission is projected to achieve emissions performance under the applicable emission guidelines.
(5) Documentation of state recordkeeping and reporting requirements to determine the performance of the plan as a whole.
(6) Demonstration that each emission standard is quantifiable, non-duplicative, permanent, verifiable, and enforceable.
EPA intends that these criteria be generally applicable to all CAA section 111(d) plans submitted on or after final new implementing regulations are promulgated, with the proviso that specific emission guidelines may provide otherwise.
Consistent with the requirements of CAA section 110(k)(1)(B) for SIPs, EPA is proposing to determine whether a state plan is complete (
When plan submissions do not contain the minimum elements, EPA is proposing to find that a state has failed to submit a complete plan through the same process as finding a state has made no submission at all. Specifically, EPA would notify the state that its submission is incomplete and therefore, that it has not submitted a required plan, and EPA would also publish a finding of failure to submit in the
As previously described, the implementing regulations were promulgated in 1975 and effectuated the 1970 version of the Clean Air Act as at it existed at that time. The 1970 version of section 111(d) required state plans to include “emission standards” for existing sources, and consequently the implementing regulations refer to this term. However, as part of the 1977 amendments to the CAA, Congress replaced the term “emission standard” in section 111(d) with “standard of performance.” EPA has not since
For these reasons, EPA is proposing to replace the existing definition of “emission standard” with a definition of “standard of performance” that tracks with the definition provided for under CAA section 111(a)(1). This means a standard of performance for existing sources would be defined as a standard for emissions or air pollutants which reflects the degree of emission limitation achievable through the application by the state of the best system of emission reduction which (taking into account the cost of achieving such reduction and any nonair quality health and environmental impact and energy requirements) the Administrator determines has been adequately demonstrated. EPA is further proposing to incorporate into a definition of standard of performance CAA section 111(h)'s allowance for design, equipment, work practice, or operational standards as alternative standards of performance under the statutorily prescribed circumstances. Currently, the existing implanting regulations allow for state plans to prescribe equipment specifications when emission rates are “clearly impracticable” as determined by EPA. CAA section 111(h)(1) by contrast allows for alternative standards such as equipment standards to be promulgated when standards of performance are “not feasible to prescribe or enforce,” as those terms are defined under CAA section 111(h)(2). Given the potential discrepancy between the conditions under which alternative standards may be established based on the different terminology used by the statute and existing implementing regulations, EPA proposes to use the “not feasible to prescribe or enforce” language as the condition for the new implementing regulations under which alternative standards may be established.
EPA solicits comment on all of these means of tracking and incorporating the section 111(a)(1) and 111(h) for purposes of a regulatory definition of “standard of performance,” and requests comment on any other considerations for such definition (Comment C-56).
EPA believes that the existing implementing regulations' distinction between public health-based and welfare-based pollutants is not a distinction unambiguously required under section 111(d) or any other applicable provision of the statute. EPA does not believe the nature of the pollutant in terms of its impacts on health and/or welfare impact the manner in which it is regulated under this provision. Particularly, 60.24(c) requires that for health-based pollutants, a state's standards of performance must be of equivalent stringency to EPA's emission guidelines. However, section 111(d)(1)(B) requires that EPA's regulations must permit states to take into account, among other factors, an affected source's remaining useful life when establishing an appropriate standard of performance. In other words, Congress explicitly envisioned under section 111(d)(1)(B) that states could implement standards of performance that vary from EPA's emission guidelines under appropriate circumstances. Notably, the implementing regulations at 40 CFR 60.24(f) contain a variance provision that allow for states to also apply less stringent standards on sources under certain circumstances. However, the variance provision attaches to the distinction between health-based and welfare-based pollutants, and is available to the states only under EPA's discretion. The variance provision was also promulgated prior to Congress's addition of the requirement in section 111(d)(1)(B) that EPA permit states to take into account remaining useful life and other factors, and the terms of the regulatory provision and statutory provision do not match one another, meaning that the variance provision may not account for all of the factors envisioned under section 111(d)(1)(B). Given all of these factors, EPA is proposing to not make a distinction between health-based and welfare-based pollutants and attach requirements contingent upon this distinction as part of the new implementing regulations. EPA is also proposing a new variance provision to permit states to take into account remaining useful life, among other factors, in establishing a standard of performance for a particular affected source, consistent with section 111(d)(1)(B).
Given that there are unique attributes and aspects of each affected source, these other factors may be ones that influence decisions to invest in technologies to meet a potential performance standard. Such other factors may include timing considerations like expected life of the source, payback period for investments, the timing of regulatory requirements, and other unit-specific criteria. EPA solicits comments on how a new variance provision can permit states to take into account remaining useful life and other factors, and what other factors might appropriately be (Comment C-57). EPA is also soliciting comment on whether the factors outlined in the existing variance provision at 40 CFR 60.24(f) are appropriate to carry over to a new variance provision if they adequately give meaning to the requirements of section 111(d)(1)(B) (Comment C-58). Those factors are:
• Unreasonable cost of control resulting from plant age, location, or basic process design;
• Physical impossibility of installing necessary control equipment; or
• Other factors specific to the facility (or class of facilities) that make application of a less stringent standard or final compliance time significantly more reasonable.
The NSR program is a preconstruction permitting program that requires stationary sources of air pollution to obtain permits prior to beginning construction. The NSR program applies both to new construction and to modifications of existing sources. New construction and modifications of
NSR permits for major sources emitting pollutants for which the area is classified as attainment or unclassifiable, and for other pollutants regulated under the CAA, are referred to as prevention of significant deterioration (PSD) permits. NSR permits for major sources emitting pollutants for which the area is in nonattainment are referred to as nonattainment NSR (NNSR) permits. The pollutant(s) at issue and the air quality designation of the area where the facility is located or proposed to be built determine the specific permitting requirements.
The test to determine whether a source is subject to major NSR differs for new stationary sources and for modifications to existing stationary sources. A new source is subject to major NSR permitting requirements if its potential to emit (PTE) any regulated NSR pollutant equals or exceeds the statutory emission threshold. For sources in attainment areas, the major source threshold is either 100 or 250 tons per year, depending on the type of source.
A modification at an existing major source is subject to major NSR permitting requirements when it is a “major modification,” which occurs when a source undertakes a physical change or change in method of operation (
As noted above, new stationary sources and modifications of stationary sources that do not require a major NSR permit may instead require a minor NSR permit prior to construction. Minor NSR permits are primarily issued by state and local air agencies. Minor NSR requirements are approved into an implementation plan in order to achieve and maintain national ambient air quality standards (NAAQS).
Since emission guidelines that are established pursuant to CAA section 111(d) apply to units at existing sources, the way in which the NSR programs treat modifications of existing sources is implicated by implementation of a CAA section 111(d) program. Specifically, in complying with the emission guidelines, a state agency may develop
With respect to the proposed action, should it be promulgated, states will be called upon to develop a section 111(d) plan that evaluates BSER technologies for each of their EGU sources and assigns emission reduction compliance obligations to their affected EGUs. Assuming the promulgated action adopts the same form as this proposal, the state may require a source with an affected EGU to achieve a HRI of a specified percentage. As described in Section VI.B of this preamble, a HRI project is designed to lower the heat rate of the EGU, which correlates to the unit consuming less fuel per kWh and emitting lower amounts of CO
Thus, it is possible that a source undertaking a HRI project at its EGU would project, or actually experience, an increase in operation of its EGU and a corresponding increase in annual emissions. This would require the source, at a minimum, to conduct an analysis to determine whether the project by itself is projected to lead to a significant emissions increase (at step one of the two-step analysis that determines whether a project constitutes a “major modification”). If so, the source would have to conduct a netting analysis to determine whether there is also a significant net increase when contemporaneous increases and decreases from other projects are considered (step two of that analysis). If both of these types of increases would be projected to occur, this could result in the source being subject to additional pollutant control requirements (
Similarly, over the years, some stakeholders have asserted that the NSR rules discourage companies from exercising the discretion to undertake energy efficiency improvement projects, which they assert results in less environmentally protective outcomes from a system-wide standpoint. Stakeholders have claimed that triggering major NSR permitting requirements can increase the costs of beneficial plant improvement projects, like HRIs, and often contribute to a company's decision to forego the projects. For instance, a commenter on the CPP proposal stated that “many coal-fired plants may refrain from making improvements based on the financial risk associated with potentially triggering a New Source Review, which may result in the requirement to invest in additional emissions controls . . . . [T]he [permitting] requirements could increase costs of potential heat rate improvements and therefore are a potential impediment which should be recognized in the rule's calculations.”
In promulgating the CPP, EPA noted that these stakeholders expressed concerns of the potential NSR permitting effects from a state implementing the rule, stating “[w]hile there may be instances in which an NSR permit would be required, we expect those situations to be few . . . states have considerable flexibility in selecting varied measures as they develop their plans to meet the goals of the emission guidelines. One of these flexibilities is the ability of the state to establish emission standards in their CAA section 111(d) plans in such a way so that their affected sources, in complying with those standards, in fact would not have emissions increases that trigger NSR. To achieve this, the state would need to conduct an analysis consistent with the NSR regulatory requirements that supports its determination that as long as affected sources comply with the emission standards in their CAA section 111(d) plan, the source's emissions would not increase in a way that trigger NSR requirements.” 80 FR 64920 (October 23, 2015). The CPP also explained that sources can voluntarily take enforceable limits on hours of operation, in the form of a synthetic minor source limitation, in order to avoid triggering major NSR requirements that would otherwise apply to the source. 80 FR 64781, 64920.
However, these concerns regarding the applicability of NSR take on even greater significance and may not be as easily avoided in the context of this proposed rule, which constrains the compliance options available in the CPP to within-the-fenceline measures and may therefore more directly result in individual sources making HRIs.
Individuals within the academic community have examined the NSR interplay with making efficiency gains at existing coal plants. A 2014 report projected that 80 percent of non-retiring coal-fired units have emissions rates for NO
Through the ANPRM, EPA took comment on the topic of how the NSR program overlays with emission guidelines established under CAA section 111(d). EPA specifically acknowledged the concerns raised previously by stakeholders regarding the potential for a source to make energy efficient improvements that could trigger major NSR requirements. Furthermore, as EPA did in the CPP, EPA described current approaches available within the NSR program to avoid triggering NSR requirements. These include the ability for a source to obtain a synthetic minor source limitation, which restricts its hours of operation and its emissions below major NSR levels, and the Plantwide Applicability Limit (PAL), which allows a source to operate within a source-wide emissions cap to avoid triggering NSR for changes.
The ANPRM solicited input on possible actions that EPA can take to harmonize and streamline the NSR applicability or the NSR permitting processes for an amended rule. EPA requested comment on ways to minimize the impact of the NSR program on the implementation of a performance standard for EGU sources under CAA section 111(d), specifically asking “[w]hat rule or policy changes or flexibilities can EPA provide as part of the NSR program that would enable EGUs to implement projects required under a CAA section 111(d) plan and not trigger major NSR permitting while maintaining environmental protections?” 82 FR 61519 (Dec. 28, 2017).
Several ANPRM commenters reiterated concerns that were raised on the CPP proposal regarding the NSR program—specifically that, if an air agency, as part of its plan to comply with emission guidelines established pursuant to CAA section 111(d), requires an affected source to make modifications (
However, other commenters disagreed. For instance, the Natural Resources Defense Council (NRDC) suggested that changes to the NSR program “are unwarranted.”
EPA acknowledges the NSR program may have unintended consequences for implementation of this emission guidelines for GHG emissions from existing EGUs. Based on the comments received on the ANPRM and EPA's experience with the NSR program generally, EPA recognizes the potential for triggering major NSR permitting when sources undertake HRI projects. EPA further recognizes that the prospect of a protracted permitting process and a possible requirement to install pollution control equipment at the emissions unit can create a disincentive for sources to voluntarily make energy efficiency
But this dynamic takes on a new character in the context of a regulation that may result in a source undertaking a HRI or another project to meet a standard of performance as determined by the state. When a state's 111(d) plan requires an EGU to comply with a standard of performance, sources cannot choose to forego a project in an effort to avoid NSR permitting as they could with improvement projects they were otherwise considering. Despite recent actions by EPA to streamline the NSR program, the reality remains that a source that undertakes a HRI project may trigger major NSR under the current NSR applicability test when required to undertake a HRI project as part of a state's 111(d) plan. As has been noted by commenters on the ANPRM, this can require the source to undertake significant planning and analysis with the process to receive a preconstruction permit, sometimes taking 3 or more years. This added time and cost to sources and the associated burden on permitting agencies could hinder the effective and prompt implementation of state 111(d) plans.
In this context, our approach in the CPP of encouraging agencies to minimize the triggering of major NSR for their affected EGUs by conducting emissions analyses as part of their CAA section 111(d) plan development does not appear to be a sufficient solution. While EPA supports states having the primary authority to implement the air programs, state agencies should not be burdened with having to determine a “work around” for the NSR program requirements in developing their plans to implement the emission guidelines for affected EGUs. The responsibility of ensuring that emission guidelines under 111(d) are clearly articulated and easily implementable rests squarely with EPA. Thus, EPA addressing the time delays and costs that can result from NSR requirements could be one tool for helping ensure the successful implementation of a national program for controlling GHG emissions from existing EGUs.
It is important for a state that is developing a CAA section 111(d) plan to completely understand the full costs being imposed on their affected sources in order for the state to make informed decisions in applying a standard of performance to each of their existing sources (much like a state would consider, among other factors, the remaining useful life of each source). However, EPA has historically not considered the costs of complying with other CAA programs, like NSR, when determining BSER for a source category under section 111. This was in part because, for many years, EPA applied a policy of excluding pollution control projects from NSR. But, as noted earlier in this section, EPA's attempt to codify such a policy in the NSR regulations was struck down by the D.C. Circuit in 2005. Since that decision, EPA has not written a significant number of rules under section 111, and the rules that EPA has written have not presented a need to consider this question. However, due to the nature of the electric utility industry and the types of candidate control measures being considered in this proposal, it may be appropriate to consider NSR compliance costs in this instance. Specifically, the BSER measures chosen in this rule may result in a source undertaking a physical change that significantly increases its annual emissions and triggers major NSR permitting requirements such that permitting costs are unavoidable. However, due to the case-specific analysis required to determine NSR applicability, it would likely be difficult for a state to adequately predict and quantify the effect of a HRI on an EGU's operational costs, change in dispatch order, and other variables that would factor into whether the source needs a major NSR permit or, perhaps, a minor NSR permit. In addition, even if a state can reasonably predict an EGU's emissions increase resulting from a HRI project such that it can expect the source will need a major NSR permit, it would likely be difficult to predict the expected permitting costs since the emission control and other permitting requirements are case-by-case determinations and can therefore vary significantly due to a number of factors, including how well the source is already controlled, the emissions from nearby sources and their contribution to air quality concerns, whether the source is located in an attainment or nonattainment area, and the potential for the air permit to trigger other requirements (
EPA is, therefore, inviting comment on whether it is appropriate to consider the costs of NSR compliance in the BSER analysis under section 111(d), assuming that triggering NSR cannot otherwise be avoided through actions by the source or through revisions to the NSR regulations that are proposed by EPA in this rule or if EPA does not finalize revisions to the NSR regulations (Comment C-59). In addition, EPA solicits comment on how a state or local permitting agency may estimate or project the cost for the source to comply with any NSR requirements that may flow from a selected BSER, and on how the potential for delays because of an influx of NSR permit applications may be accounted for in setting an implementation schedule for 111(d) plans (Comment C-60).
Recognizing that EPA issuing this 111(d) rule would mean that a source may no longer be in a position to forego a HRI project due to unwanted permitting costs, EPA has continued to look for ways to reduce the costs of NSR requirements, while being mindful of the requirements of the CAA and the court decisions on prior NSR reform rules that were referenced by some commenters. In this light, EPA believes that a past option for revising the NSR regulation that EPA has considered may warrant further consideration to address this concern. In 2005 and 2007, EPA previously proposed adopting an hourly emissions rate test for NSR applicability for EGUs. While this rulemaking was never completed, EPA believes that it warrants a fresh look in a new context here where NSR program flexibility takes on added significance as a means to facilitate the HRI projects that are expected to be undertaken should the proposed ACE rule be finalized. This same idea was also raised by a few
In 2007, EPA proposed to revise the NSR provisions to include an NSR applicability test for EGUs that is based on maximum hourly emissions. 72 FR 26202 (May 8, 2007). The 2007 proposed action was a “supplemental” notice of proposed rulemaking (SNPRM), because the 2007 proposal followed an earlier action by EPA that proposed a more limited form of the hourly emissions test for NSR applicability. 70 FR 61081 (October 20, 2005) (NPRM). These proposals followed EPA's NSR regulatory reform efforts of 2002 and 2003, when EPA promulgated final regulations that implemented several of the recommendations in the New Source Review Report to the President.
The 2007 SNPRM requested comment on two basic options, and various alternatives within each of the two options, for changing the test for determining an emissions increase from an EGU undergoing a physical or operational change. The proposal included emissions test alternatives based on an EGU's maximum
For the proposed maximum achieved hourly test alternatives, an EGU owner/operator would determine whether an emissions increase would occur by comparing the pre-change maximum actual hourly emissions rate to a projection of the post-change maximum actual hourly emissions rate. In establishing the baseline, both alternatives considered the unit's actual performance during the 5-year period immediately preceding the physical or operational change. For the one-in-5-year baseline approach, the emissions rate would be computed based on what the unit actually achieved for any single hour within the 5-year period immediately before the physical or operational change. For the statistical approach, the owner/operative would analyze continuous emission monitoring system (CEMS) or predictive emission monitoring system (PEMS) data from the 5 years preceding the physical or operational change to determine the maximum actual pollutant emissions rate. The statistical approach would utilize actual recorded data from periods of representative operation to calculate the maximum actual emissions rate associated with the pre-change maximum actual operating capacity in the past 5 years.
The purpose behind developing the statistical approach was to address concerns from comments received on the 2005 NPRM “that maximum achievable emissions could differ from maximum achieved emissions for a given EGU for any given period as a result of factors independent of the physical or operational change, including variability of the sulfur content in the coal being burned.” 72 FR 26219 (May 8, 2007). In the 2007 SNPRM, EPA acknowledged that the highest hourly emissions do not always occur at the point of highest capacity utilization, due to fluctuations in process and control equipment operation, as well as in fuel content and firing method. The proposed statistical procedure would consequently ensure that the maximum achieved hourly emissions test identified the maximum hourly pollutant emissions value. Specifically, the statistical procedure would estimate the highest value (99.9 percentage level) in the period represented by the data set compiled from hourly average CEMS or PEMS measured emission rates and corresponding heat input data. EPA asserted that this approach would mitigate some of the uncertainty associated with trying to identify the highest hourly emissions rate at the highest capacity utilization. EPA asserted then that “over a period that is representative of normal operations, in general the maximum achievable and maximum achieved hourly emissions test would lead to substantially equivalent results.” 72 FR 26220.
For the proposed maximum achievable hourly test alternatives, the major NSR regulations would apply at an EGU if a physical or operational change results in any increase above the maximum hourly emissions achievable at that unit during the 5 years prior to the change. Pre-change and post-change hourly emissions rates would be determined according to the NSPS provisions in § 60.14(b). Hourly emission increases would be determined using emission factors, material balances, continuous monitor data, or manual emission tests.
In the 2007 SNPRM, EPA argued that a maximum hourly emissions test would simplify major NSR applicability determinations and implementation. EPA contended that “the achieved and achievable [hourly emissions] tests eliminate the burden of projecting future emissions and distinguishing between emissions increases caused by the change from those due solely to demand growth, because any increase in the emissions under the hourly emissions tests would logically be attributed to the change. Both the achieved and achievable tests reduce recordkeeping and reporting burdens on sources because compliance will no longer rely on synthesizing emissions data into rolling average emissions.” 72 FR 26206 (May 8, 2007).
While the 2005 action had proposed to replace the current NSR annual emissions increase test with an hourly test, the 2007 action proposed the same option as well as an option to retain the annual emissions test along with an hourly test. For the combined hourly and annual emissions option, if a change would not increase the hourly emissions of the EGU, major NSR would not apply; however, if hourly emissions would increase after the change, then projected annual emissions would be reviewed using the existing NSR applicability test. The 2007 SNPRM expressed a preference for this combined applicability option.
In the 2007 SNPRM, the proposed changes to the NSR emissions test were in part justified by the substantial EGU emission reductions from other air programs enacted since 1980 and the capped emissions approaches used for
These 2005 and 2007 proposed rules were neither finalized nor withdrawn by EPA. The rulemaking docket for these actions is EPA-HQ-OAR-2005-0163.
The 2007 SNPRM followed EPA's NPRM from 2005 that would have
The case then went to the Supreme Court, and the Supreme Court disagreed. In
Of particular significance here, the Supreme Court also addressed the possibility that the two regulatory programs could be read together as set and subset, such than an NSPS-type modification was a prerequisite to an NSR-type modification—
In the 2007 SNPRM, EPA argued that the Supreme Court decision left room for EPA to revise the regulations when it has a rational basis for doing so. 72 FR 26202, 26204 (May 8, 2007);
In the 2007 action, EPA also explained how an applicability test based on maximum achievable hourly emissions is, in fact, a test based on actual emissions. The reason is that, as a practical matter, “for most, if not all EGUs, the hourly rate at which the unit is actually able to emit is substantively equivalent to that unit's historical maximum hourly emissions. That is, most, if not all EGUs will operate at their maximum actual physical and operational capacity at some point in a 5-year period. In general, the highest emissions occur during the period of highest utilization. As a result, both the maximum achievable and maximum achieved hourly emissions increase tests allow an EGU to utilize all of its existing capacity, and in this aspect the hourly rate at which the unit is actually able to emit is substantively equivalent under both tests.” 72 FR 26219 (May 8, 2007).
Thus, EPA considered the approaches proposed in the 2007 SNPRM to be consistent with the D.C. Circuit precedent which held that the 2002 NSR Reform Rule's “Clean Unit” provision was beyond EPA's authority because Congress intended to apply NSR to increases in actual emissions, even though the decision deferred to EPA on the method for calculating baseline emissions.
At the same time, the D.C. Circuit affirmed that EPA has wide discretion to interpret the definition of “modification” within these bounds. The court rejected challenges brought to the 2002 NSR Reform Rule's then-new baseline period provision, finding that “[i]n enacting the NSR program, Congress did not specify how to calculate `increases' in emissions,” with the result that it was left to EPA “to fill that gap while balancing the economic and environmental goals of the statute.” 413 F.3d at 27. Because the CAA is “silent on how to calculate . . . `increases' in emissions” for purposes of determining “modification,” the court said,
As for NRDC's argument in comments on the ANPRM that narrowing the scope of projects subject to NSR requirements would be contrary to the D.C. Circuit's
Consistent with our policy goal of encouraging efficient use of existing energy capacity and managing the burden on states of developing and implementing their CAA section 111(d) plans, EPA is proposing to amend the NSR regulations to include an hourly emissions increase test for EGUs. These proposed changes could be one tool that states may use to help ensure the efficient and effective implementation of their 111(d) plans.
EPA is proposing some of the same alternatives for an hourly emissions test that EPA proposed in 2007. The 2007 SNPRM solicited comment on 12 alternatives, but EPA is narrowing the number of alternatives for this revised proposal and solicitation of comment. In this case, EPA is proposing only alternatives in which the hourly test is paired with the current NSR annual emissions test (
Thus, under this proposed approach, the major NSR program would include a four-step applicability process (with the second step inserted as proposed, while retaining the other steps): (1) A physical change or change in the method of operation as in the current major NSR regulations; (2) an hourly emissions increase test (either maximum achieved hourly emissions rate or maximum achievable hourly emissions rate, each on an input-basis (lb/hr)); (3) a significant emissions increase as in the current major NSR regulations; and (4) a significant net emissions increase as in the current major NSR regulations. For a major modification to occur, under Step 1, a physical change or change in the method of operation must occur. If there is a physical change or change in
This proposed approach would not alter the provisions in the current major NSR regulations pertaining to a significant emissions increase and a significant net emissions increase. Therefore, the NSR regulations would retain the definitions of net emissions increase, significant, projected actual emissions, and baseline actual emissions.
To incorporate the four-step modification provisions, EPA is proposing to add two new sections to the major NSR program rules. The first, 40 CFR 51.167, would specify that State Implementation Plans may include a new Step 2 for major NSR applicability at existing EGUs, including those for both attainment and nonattainment areas. The second, 40 CFR 52.25, would contain the requirements for major NSR applicability for existing EGUs where EPA is the reviewing authority or EPA has delegated our authority to a state or local air permitting agency. EPA is also proposing to make the same changes where necessary to conform the general provisions in parts 51 and 52 to the requirements of the major NSR program, such as in the definition of modification in 40 CFR 52.01. The new sections at § 51.167 and § 52.25 will be separate and distinct from the other NSR provisions and this will allow our rules to apply this new proposed Step 2 to EGUs while keeping the current distinction in our NSR rules that applies different applicability requirements for EUSGUs and non-EUSGUs that are not EGUs.
While EPA is proposing that this NSR hourly emissions test would apply to all EGUs, as defined in 40 CFR 51.124(q), EPA is soliciting comment on whether to confine the applicability of the hourly test to a smaller subset of the power sector, such as only the affected EGUs that are making modifications to comply with their state's standards of performance pursuant to these section 111(d) emissions guidelines (
Recognizing that existing case law dictates that the phrase “increases the amount of any air pollutant” in CAA section 111(a)(4) refers to increases in actual emissions for NSR purposes, in 2007 EPA argued that an hourly achievable test is equivalent to a measure of actual emissions because “for most, if not all EGUs, the hourly rate at which the unit is actually able to emit is substantively equivalent to that unit's historical maximum hourly emissions.” 72 FR 26219 (May 8, 2007). EPA is taking comment on this prior assertion and whether recent changes to the energy sector may have rendered it invalid (Comment C-63). EPA is also asking for comment on whether if, practically speaking, maximum achieved and maximum achievable hourly rates are equivalent for most if not all EGUs, EPA has the flexibility under the CAA to implement an hourly achievable emissions test for NSR (Comment C-64).
As noted in the preceding section, EPA's proposal in 2007 to adopt an hourly emissions increase test for NSR included an analysis demonstrating that (1) the proposed regulations would not have an undue adverse impact on local air quality, and (2) increases in the hours of operation at EGUs, to the extent they may increase under a maximum hourly rate test for NSR, would not notably increase national SO
While recognizing that fewer sources will trigger major NSR under an hourly emissions increase, we note that even if a source undertaking a heat rate improvement is not subject to major NSR requirements, it will often require a minor NSR permit from its permitting agency. As noted in Section VIII.A of this preamble, the minor NSR program applies to new and modified sources that are not subject to major NSR permitting. The purpose of a minor NSR program is, along with major NSR, to ensure that sources of air emissions are properly regulated so that the NAAQS are attained and protected. For example, under EPA's tribal minor NSR program, the reviewing authority (
Furthermore, states use measures contained in their State Implementation Plan (SIP) to ensure that local air quality impacts are addressed or minimized to the extent possible. A SIP may include (1) state-adopted control measures which consist of either regulations or source-specific requirements (
Supplementing the Agency's legal and policy rationale provided in the 2007 SNPRM, EPA is taking comment on an important factor that EPA believes supports for moving forward with the addition of an NSR hourly emissions test for EGUs: EPA is now proposing a rule that could result in sources being required to perform HRIs (as determined by their state 111(d) plans) rather than sources independently deciding to do them (Comment C-66). EPA believes this added factor of the 111(d) GHG emission guidelines for EGUs directing sources to consider HRIs when complying with their state plans may make the case for adopting an NSR hourly emissions test for EGUs more compelling. EPA requests comment on the extent to which EPA should allow the adoption of an NSR hourly emissions test for EGUs in light of EPA's decision to issue these proposed emission guidelines for the power sector (Comment C-67).
EPA is also taking comment on other ways to minimize or eliminate any adverse impact that NSR may have on implementing section 111(d) plans for EGUs (Comment C-68). Specifically, have there been court decisions since
For example, when EPA undertook the challenge of applying the PSD program to GHGs, the Supreme Court pointed to several instances where EPA had permissibly narrowed the scope of the general CAA definition of “air pollutant” based on the surrounding context of provisions within which the term is used, including the NSR program.
The requirements of the CAA section 111 program were intended to work in harmony with NSR and other provisions of the Act. The complementary relationship of the programs is evident from the statutory requirements. Both programs are intended to protect air quality from stationary sources of pollution, and they rely on many of the same CAA provisions and definitions—namely, the programs' framework for existing sources are both rooted in the same definition for “modification.” In addition, there are instances in which the CAA cross links the programs such that a requirement from one program bears an influence on the other program. For example, in accordance with CAA section 169(3), an applicable standard of performance under NSPS establishes the minimum level of stringency for BACT for a source getting a PSD permit. Similarly, LAER must reflect an emission rate that is does not exceed the allowable emission rate under any applicable NSPS. CAA section 171(3). Thus, the NSPS program sets the minimum performance standards for new stationary sources as part of program to ensure air quality is protected, and NSR authorizes the construction or modification of sources of air pollution, taking into account the NSPS as it examines what the source needs to do to control its emissions in order to adequately protect or improve air quality.
Thus, EPA believes the two programs are intended to complement—not conflict with—each other. However, because changes considered under 111(d) plans could result in a source triggering NSR under the current NSR rules and increasing the costs to the point that undertaking HRI are less financially feasible for some sources, can EPA apply the reasoning of
As the hourly emissions test for NSR would be one tool for implementing the ACE rule, EPA expects that some states may determine that they do not need or desire to change the NSR applicability requirements for EGUs. Consequently, EPA does not intend the NSR hourly emissions test to be a mandatory element of state programs (as EPA had proposed in 2007). EPA is proposing for this action that states would have the discretion to decide whether to incorporate the NSR hourly emissions test for EGUs into their rules. However, state and local permitting authorities that are issuing permits on behalf of EPA under a delegation agreement will be required to apply the NSR hourly emissions test for EGUs, since they would follow the Federal NSR program provided in 40 CFR part 52 (which would be amended to include section
Although EPA proposes to finalize these NSR revisions as part of an integrated action with the rest of this proposal, EPA views the revisions to the definition of BSER, revisions to the implementing regulations, and emission guideline proposed in this proposal as appropriate policies in their own right and on their own terms. EPA intends that the NSR revisions, if finalized, would be severable from the other provisions on judicial review. EPA solicits comment on whether it would be appropriate to finalize the NSR revisions as a separate action from the remainder of the proposal (Comment C-71).
Please submit all comments on this NSR section docket established for this rulemaking (Docket ID number EPA-HQ-OAR-2017-0355). To the extent that you previously commented on the October 20, 2005 NPRM and/or May 8, 2007 SNPRM and desire for your comments to be considered for this proposed action, please resubmit them.
In the Regulatory Impact Analysis (RIA) for this proposed rulemaking, the Agency provides a full benefit cost analysis of four illustrative scenarios. The four illustrative scenarios include a scenario modeling the full repeal of the CPP (which can also be conceptualized as the legal state of affairs as of the date of this proposal, given the Supreme Court stay of the CPP) and three policy scenarios modeling heat rate improvements (HRI) at coal-fired EGUs. Throughout the RIA, these three illustrative policy scenarios are compared against a base case, which includes the CPP. By analyzing against the CPP, the reader can understand the combined impact of the CPP repeal and proposed ACE rule. Inclusion of a no CPP case allows for an understanding of the repeal alone and also allows the reader to evaluate the impact of the policy cases against a no CPP scenario. The RIA assumes a mass-based implementation of the CPP for existing affected sources, and does not assume interstate trading. The three illustrative policy scenarios represent potential outcomes of state determinations of standards of performance, and compliance with those standards by affected coal-fired EGUs. These policy scenarios illustrate the analysis of the world without the CPP, the world with this proposal, and the difference in the effects of this proposal and those of the CPP.
The illustrative policy scenarios model different levels and costs of HRIs applied uniformly at all affected coal-fired EGUs in the contiguous U.S. beginning in 2025. EPA has identified the BSER to be HRI. Each of these illustrative scenarios assumes that the affected sources are no longer subject to the state plan requirements of the CPP (
The first illustrative scenario, 2 Percent HRI at $50/kW, represents a policy case that reflects modest improvements in HRI absent any revisions to NSR requirements. For many years, industry has indicated to the Agency that many sources have not implemented certain HRI projects because the burdensome costs of NSR cause such projects to not be viable. Thus, absent NSR reform, HRI at affected units might be expected to be modest. Based on numerous studies and statistical analysis, the Agency believes that the HRI potential for coal-fired EGUs will, on average, range from one to three percent at a cost of $30 to $60 per kilowatt (kW) of EGU generating capacity. The Agency believes that this scenario (2 percent HRI at $50/kW) reasonably represents that range of HRI and cost.
The second illustrative scenario, 4.5 Percent HRI at $50/kW, represents a policy case that includes benefits from the proposed revisions to NSR, with the HRI modeled at a low cost. As mentioned earlier, the Agency is proposing revisions to the NSR program that will provide owners and operators of existing EGUs greater ability to make efficiency improvements without triggering the provisions of NSR. This scenario is informative in that it represents the ability of all coal-fired EGUs to obtain greater improvements in heat rate because of NSR reform at the $50/kW cost identified earlier. EPA believes this higher heat rate improvement potential is possible because without NSR a greater number of units may have the opportunity to make cost effective heat rate improvements such as steam turbine upgrades that have the potential to offer greater heat rate improvement opportunities.
The third illustrative scenario, 4.5 Percent HRI at $100/kW, represents a policy case that includes the benefits from the proposed revisions to NSR, with the HRI modeled at a higher cost. This scenario is informative in that it represents the ability of a typical coal-fired EGU to obtain greater improvements in heat rate because of NSR reform but at a much higher cost ($100/kW) than the $50/kW cost identified earlier. Particularly for lower capacity units or those with limited remaining useful life, this could ultimately translate into HRI projects with costs beyond what most states might determine to be reasonable.
Combined, the 4.5 percent HRI at $50/kW scenario and the 4.5 percent HRI at $100/kW scenario represent a range of potential costs for the proposed policy option that couples HRI with NSR reform. Modeling this at $50/kW and $100/kW provides a sensitivity analysis on the cost of the proposed policy including NSR reform. The $50/kW cost represents an optimistic bounding where NSR reform unleashes significant new opportunity for low-cost heat rate improvements. The $100/kW cost scenario, while informative, represents a high-end bound that could overstate potential because, particularly for lower capacity factor units and those with limited remaining useful life, these would represent project costs that states would likely find to be unreasonable.
The Agency understands that there may be interest in comparing the three illustrative policy scenarios against an alternative baseline that does not include the CPP. For those interested in comparing the potential impacts of the policy scenarios in a world without the CPP, results from the three illustrative policy scenarios may be compared against an alternative baseline results from the illustrative No CPP scenario. The presentation of an alternative baseline is consistent with Circular A-4, which states, “When more than one
EPA evaluates the potential regulatory impacts of the illustrative No CPP scenario and the three illustrative policy scenarios using the present value (PV) of costs, benefits, and net benefits, calculated for the years 2023-2037 from the perspective of 2016, using both a three percent and seven percent beginning-of-period discount rate. In addition, the Agency presents the assessment of costs, benefits, and net benefits for specific snapshot years, consistent with historic practice. In the RIA, the regulatory impacts are evaluated for the specific years of 2025, 2030, and 2035.
Emissions are projected to be higher under the three illustrative policy scenarios and the illustrative No CPP scenario than under the base case, as the base case includes the CPP. Table 6 shows projected emission increases relative to the base case for CO
The proposed actions have energy market implications. Overall, the analysis to support this proposed rule indicates that there are important power sector impacts that are worth noting, although they are relatively small compared to other EPA air regulatory actions for EGUs. The estimated impacts reflect EPA's illustrative analysis of the proposed rule, which applies various levels of heat rate improvements to affected sources in order to ascertain how they might respond, in order to capture the potential systemwide economic and energy impacts of the requirements. States are afforded considerable flexibility in this proposed rule, and thus the impacts could be different, to the extent states make different choices.
Table 8 presents a variety of energy market impacts for 2025, 2030, and 2035 for the four illustrative scenarios, relative to the base case, which includes the CPP.
Energy market impacts are discussed more extensively in the RIA found in the rulemaking docket.
The power industry's “compliance costs” are represented in this analysis as the change in electric power generation costs between the base case and illustrative scenarios, including the cost of monitoring, reporting, and recordkeeping (MR&R). In simple terms, these costs are an estimate of the increased power industry expenditures required to implement the HRI required by the proposed rule, minus the sectoral cost of complying with the CPP assumed in the base case.
The compliance assumptions—and, therefore, the projected compliance costs—set forth in this analysis are illustrative in nature and do not represent the plans that states may ultimately pursue. The illustrative compliance scenarios are designed to reflect, to the extent possible, the scope and nature of the proposed guidelines. However, there is considerable uncertainty with regards to the precise measure that states will adopt to meet the proposed requirements, because there are considerable flexibilities afforded to the states in developing their state plans.
Table 9 presents the annualized compliance costs of the three illustrative policy scenarios and the illustrative No CPP scenario. In this table, and throughout the RIA for this proposed rulemaking, negative costs indicate avoided costs relative to the base case (which includes the CPP), and positive costs indicate an increase in projected compliance costs, relative to the base case. As shown in Table 9, the Agency estimates that there are avoided costs under three out of the four illustrative scenarios. Table 7 shows the same compliance cost information, except relative to the No CPP alternative baseline.
Due to a number of changes in the electricity sector since the CPP was finalized, as documented in the October 2017 RIA conducted for the proposed CPP repeal and Chapter 3 of the RIA for this action, the sector has become less carbon intensive over the past several years, and the trend is projected to continue. These changes and trends are reflected in the modeling used for this analysis. As such, achieving the emissions levels required under CPP requires less effort and expense, relative to a scenario without the CPP, and the estimated compliance costs are significantly lower than what was estimated in the final CPP RIA. More detailed cost estimates are available in the RIA included in the rulemaking docket.
Environmental regulation may affect groups of workers differently, as changes in abatement and other compliance activities cause labor and other resources to shift. An employment impact analysis describes the characteristics of groups of workers potentially affected by a regulation, as well as labor market conditions in affected occupations, industries, and geographic areas. Market and employment impacts of this proposed action are discussed more extensively in Chapter 5 of the RIA for this proposed rulemaking.
EPA reports the impact on climate benefits from changes in CO
The estimated health co-benefits are the monetized value of the forgone human health benefits among populations exposed to changes in PM
Table 14 reports the combined domestic climate benefits and ancillary health co-benefits attributable to changes in SO
In this table, negative benefits indicate forgone benefits, relative to the base case, which includes the CPP. As all benefit estimates in this table are negative values, this indicates that the Agency estimates there to be forgone climate benefits and forgone ancillary health co-benefits under all four illustrative scenarios in the years and discount rates analyzed relative to the base case.
In general, EPA is more confident in the size of the risks estimated from simulated PM
To give readers insight to the distribution of estimated forgone benefits displayed in Table 14, EPA also reports the PM benefits according to alternative concentration cut-points and concentration-response parameters. The percentage of estimated PM
Monetized co-benefits estimates shown here do not include several important benefit categories, such as direct exposure to SO
Additional information about these Statutory and Executive Orders can be found at
This proposed action is an economically significant action that was
In the RIA for this proposed rulemaking, the Agency presents full benefit cost analysis of four illustrative scenarios. The four illustrative scenarios include a scenario modeling the full repeal of the CPP and three policy scenarios modeling heat rate improvements (HRI) at coal-fired EGUs. Throughout the RIA, these three illustrative policy scenarios are compared against a base case, which includes the CPP. By analyzing against the CPP, the reader can understand the combined impact of a CPP repeal and proposed ACE rule. Inclusion of a No CPP case allows for an understanding of the repeal alone and also allows the reader to evaluate the impact of the policy cases against a No CPP scenario. The RIA assumes a mass-based implementation of the CPP for existing affected sources, and does not assume interstate trading. The three illustrative policy scenarios represent potential outcomes of state determinations of standards of performance, and compliance with those standards by affected coal-fired EGUs.
The Agency understands that there may be interest in comparing the three illustrative policy scenarios against a scenario that does not include the CPP. For those interested in comparing the potential impacts of policy scenarios in a world without the CPP, results from the three illustrative policy scenarios may be compared against results from the illustrative No CPP scenario. We provide information here on compliance costs, emissions impacts and present value net benefits compared to the No CPP alternative baseline. In addition, the Executive Summary and Chapter 3 of the RIA compares the three illustrative policy scenarios to the scenario of a full CPP repeal. Also, the full suite of model outputs is available in the rulemaking docket.
The three illustrative policy scenarios model different levels and costs of HRIs applied uniformly at all affected coal-fired EGUs in the contiguous U.S. beginning in 2025. EPA has identified the BSER to be HRI. Each of these illustrative scenarios assumes that the affected sources are no longer subject to the state plan requirements of the CPP (
To avoid the impression that EPA can sufficiently distinguish likely standards of performance across individual affected units and their compliance strategies, this analysis assumes different HRI levels and costs are applied uniformly to affected coal-fired EGUs under each of three illustrative policy scenarios.
The first illustrative scenario, 2 Percent HRI at $50/kW, represents a policy case that reflects modest improvements in HRI absent any revisions to NSR requirements. For many years, industry has indicated to the Agency that many sources have not implemented certain HRI projects because the burdensome costs of NSR cause such projects to not be viable. Thus, absent NSR reform, HRI at affected units might be expected to be modest. Based on numerous studies and statistical analysis, the Agency believes that the HRI potential for coal-fired EGUs will, on average, range from one to three percent at a cost of $30 to $60 per kilowatt (kW) of EGU generating capacity. The Agency believes that this scenario (2 percent HRI at $50/kW) reasonably represents that range of HRI and cost.
The second illustrative scenario, 4.5 Percent HRI at $50/kW, represents a policy case that includes benefits from the proposed revisions to NSR, with the HRI modeled at a low cost. As mentioned earlier, the Agency is proposing revisions to the NSR program that will provide owners and operators of existing EGUs greater ability to make efficiency improvements without triggering provisions of NSR. This scenario is informative in that it represents the ability of all coal-fired EGUs to obtain greater improvements in heat rate because of NSR reform at the $50/kW cost identified earlier. EPA believes this higher heat rate improvement potential is possible because without NSR a greater number of units may have the opportunity to make cost effective heat rate improvements such as turbine upgrades that have the potential to offer greater heat rate improvement opportunities.
The third illustrative scenario, 4.5 Percent HRI at $100/kW, represents a policy case that includes the benefits from the proposed revisions to NSR, with the HRI modeled at a higher cost. This scenario is informative in that it represents the ability of a typical coal-fired EGUs to obtain greater improvements in heat rate because of NSR reform but at a much higher cost ($100/kW) than the $50/kW cost identified earlier. Particularly for lower capacity units or those with limited remaining useful life, this could ultimately translate into HRI projects with costs beyond what most states might determine to be reasonable.
Combined, the 4.5 percent HRI at $50/kW scenario and the 4.5 percent HRI at $100/kW scenario represent a range of potential costs for the proposed policy option that couples HRI with NSR reform. Modeling this at $50/kW and $100/kW provides a sensitivity analysis on the cost of the proposed policy including NSR reform. The $50/kW cost represents an optimistic bounding where NSR reform unleashes significant new opportunity for low-cost heat rate improvements. The $100/kW cost scenario, while informative, represents a high-end bound that could overstate potential because, particularly for lower capacity factor units and those with limited remaining useful life, these would represent project costs that states would likely find to be unreasonable.
We evaluate the potential regulatory impacts of the illustrative No CPP scenario and the three illustrative policy scenarios using the present value (PV) of costs, benefits, and net benefits, calculated for the years 2023-2037 from the perspective of 2016, using both a three percent and seven percent beginning-of-period discount rate. In addition, the Agency presents the assessment of costs, benefits, and net benefits for specific snapshot years, consistent with historic practice. In the RIA, the regulatory impacts are evaluated for the specific years of 2025, 2030, and 2035.
The power industry's “compliance costs” are represented in this analysis as the change in electric power generation costs between the base case and illustrative scenarios, including the cost of monitoring, reporting, and recordkeeping (MR&R). In simple terms, these costs are an estimate of the increased power industry expenditures required to implement the HRI required by the proposed rule, minus the sectoral cost of complying with the CPP assumed in the base case.
The compliance assumptions—and, therefore, the projected compliance costs—set forth in this analysis are
EPA reports the impact on climate benefits from changes in CO
The health co-benefits estimates represent the monetized value of the forgone human health benefits among populations exposed to changes in PM
In general, we are more confident in the size of the risks we estimate from simulated PM
Furthermore, when setting the 2012 PM NAAQS, the Administrator also acknowledged greater uncertainty in specifying the “magnitude and significance” of PM-related health risks at PM concentrations below the NAAQS. As noted in the preamble to the 2012 PM NAAQS final rule, “EPA concludes that it is not appropriate to place as much confidence in the magnitude and significance of the associations over the lower percentiles of the distribution in each study as at and around the long-term mean concentration.” (78 FR 3154, 15 January 2013). In general, we are more confident in the size of the risks we estimate from simulated PM
To give readers insight to the distribution of estimated forgone benefits displayed in Table 14, EPA also reports the PM benefits according to alternative concentration cut-points and concentration-response parameters. To give readers insight to the uncertainty in the estimated forgone PM
Monetized co-benefits estimates shown here do not include several important benefit categories, such as direct exposure to SO
In the decision-making process it is useful to consider the change in benefits due to the targeted pollutant relative to the costs. Therefore, in Chapter 6 of the RIA for this proposed rulemaking we present a comparison of the benefits from the targeted pollutant—CO
Table 15 presents the present value (PV) and equivalent annualized value (EAV) of the estimated costs, benefits, and net benefits associated with the targeted pollutant, CO
In Table 15, and all net benefit tables, negative costs indicate avoided costs, negative benefits indicate forgone benefits, and negative net benefits indicate forgone net benefits.
Throughout the RIA for this proposed rulemaking, EPA examines a number of sources of uncertainty, both quantitatively and qualitatively, on benefits and costs. Some of these elements are evaluated using probabilistic techniques. For other elements, where the underlying likelihoods of certain outcomes are unknown, we use scenario analysis to evaluate their potential effect on the benefits and costs of this proposed
• The extent to which all coal-fired EGUs will improve heat rates under this proposal, on average;
• The cost to improve heat rates at all affected coal-fired EGUs nationally;
• Uncertainty in monetizing climate-related benefits; and,
• Uncertainty in the estimated health impacts attributable to changes in particulate matter.
In the RIA for this proposed rulemaking, EPA also summarize other potential sources of benefits and costs that may result from this proposed rule that have not been quantified or monetized.
This action is expected to be an Executive Order 13771 deregulatory action. Details on the estimated cost savings of this proposed rule can be found in the rule's RIA.
The information collection activities in this proposed rule have been submitted for approval to the Office of Management and Budget (OMB) under the PRA. The Information Collection Request (ICR) document that EPA prepared has been assigned EPA ICR number 2503.03. You can find a copy of the ICR in the docket for this rule, and it is briefly summarized here.
The information collection requirements are based on the recordkeeping and reporting burden associated with developing, implementing, and enforcing a state plan to limit CO
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 EPA's regulations in 40 CFR are listed in 40 CFR part 9.
Submit your comments on the Agency's need for this information, the accuracy of the provided burden estimates and any suggested methods for minimizing respondent burden to EPA using the docket identified at the beginning of this rule (Comment C-72). You may also send your ICR-related comments to OMB's Office of Information and Regulatory Affairs via email to
After considering the economic impacts of this proposed rule on small entities, I certify that this action will not have a significant economic impact on a substantial number of small entities. The proposed rule will not impose any requirements on small entities. Specifically, emission guidelines established under CAA section 111(d) do not impose any requirements on regulated entities and, thus, will not have a significant economic impact upon a substantial number of small entities. After emission guidelines are promulgated, states establish emission standards on existing sources, and it is those state requirements that could potentially impact small entities. Our analysis in the accompanying RIA is consistent with the analysis of the analogous situation arising when EPA establishes NAAQS, which do not impose any requirements on regulated entities. As with the description in the RIA, any impact of a NAAQS on small entities would only arise when states take subsequent action to maintain and/or achieve the NAAQS through their state implementation plans.
Nevertheless, EPA is aware that there is substantial interest in the proposed rule among small entities (municipal and rural electric cooperatives) and we invite comments on all aspects of the proposal and its impacts, including potential impacts on small entities (Comment C-73).
This action does not contain a federal mandate that may result in expenditures of $100 million or more for state, local and tribal governments, in the aggregate or the private sector in any one year. Specifically, the emission guidelines proposed under CAA section 111(d) do not impose any direct compliance requirements on regulated entities, apart from the requirement for states to develop state plans. The burden for states to develop state plans in the three-year period following promulgation of the rule was estimated and is listed in Section IX.C above, but this burden is estimated to be below $100 million in any one year. Thus, this proposed rule is not subject to the requirements of section 203 or section 205 of the Unfunded Mandates Reform Act (UMRA).
This proposed rule is also not subject to the requirements of section 203 of UMRA because, as described in 2 U.S.C. 1531-38, it contains no regulatory requirements that might significantly or uniquely affect small governments. This action imposes no enforceable duty on any state, local, or tribal governments or the private sector.
Under Executive Order 13132, EPA may not issue an action that has federalism implications, that imposes substantial direct compliance costs and that is not required by statute unless the federal government provides the funds necessary to pay the direct compliance costs incurred by state and local governments, or EPA consults with state and local officials early in the process of developing the proposed action.
EPA has concluded that this action may have federalism implications because it might impose substantial direct compliance costs on state or local governments, and the federal government will not provide the funds necessary to pay those costs. The development of state plans will entail many hours of staff time to develop and coordinate programs for compliance with the proposed rule, as well as time to work with state legislatures as appropriate, and develop a plan submittal.
In the spirit of Executive Order 13132, and consistent with EPA's policy to promote communications between EPA and state and local governments, EPA specifically solicits comment on this
This action does not have tribal implications as specified in Executive Order 13175. It would not impose substantial direct compliance costs on tribal governments that have affected EGUs located in their area of Indian country. Tribes are not required to develop plans to implement the guidelines under CAA section 111(d) for affected EGUs. EPA notes that this proposal does not directly impose specific requirements on EGU sources, including those located in Indian country, but before developing any standards for sources on tribal land, EPA would consult with leaders from affected tribes. This proposed action also will not have substantial direct effects on the relationship between the federal government and Indian tribes or on the distribution of power and responsibilities between the federal government and Indian tribes, as specified in Executive Order 13175. Thus, Executive Order 13175 does not apply to the action.
Consistent with EPA Policy on Consultation and Coordination with Indian Tribes, EPA will engage in consultation with tribal officials during the development of this action.
This proposed action is subject to Executive Order 13045 because it is an economically significant regulatory action as defined by Executive Order 12866. The CPP, as discussed in the RIA,
Moreover, this proposed action does not affect the level of public health and environmental protection already being provided by existing NAAQS, including ozone and PM
This proposed action, which is a significant regulatory energy action under Executive Order 12866, is likely to have a significant effect on the supply, distribution, or use of energy. Specifically, EPA estimated in the RIA that the proposed rule could result in up to a 3 percent reduction in natural gas use in the power sector (or more than a 25 MM MCF reduction in production on an annual basis).
The energy impacts EPA estimates from the proposed rule may be under- or over-estimates of the true energy impacts associated with this action. For example, some states are likely to pursue emissions reduction strategies independent of EPA action.
This proposed rulemaking does not involve technical standards. EPA welcomes comments on this aspect of the proposed rulemaking and specifically invites the public to identify potentially-applicable voluntary consensus standards and to explain why such standards should be used in this action (Comment C-75).
EPA believes that this proposed action is unlikely to have disproportionately high and adverse human health or environmental effects on minority populations, low-income populations and/or indigenous peoples as specified in Executive Order 12898 (59 FR 7629, February 16, 1994). The CPP, as discussed in the RIA,
Moreover, this proposed action does not affect the level of public health and environmental protection already being provided by existing NAAQS, including ozone and PM
The statutory authority for this action is provided by sections 111, 301, and 307(d)(1)(V) of the CAA, as amended (42 U.S.C. 7411, 7601, 7607(d)(1)(V)). This action is also subject to section 307(d) of the CAA (42 U.S.C. 7607(d)).
Environmental protection, Intergovernmental relations, Reporting and recordkeeping requirements.
Environmental protection, Air pollution control, Incorporation by reference, Intergovernmental relations, Reporting and recordkeeping requirements.
Environmental protection, Administrative practice and procedure, Incorporation by reference, Intergovernmental relations, Reporting and recordkeeping requirements.
For the reasons stated in the preamble, EPA proposes to amend 40 CFR parts 51, 52, and 60 as set forth below:
23 U.S.C. 101; 42 U.S.C. 7401-7671q.
(a)
(b)
(c)
(d)
(1)
(2)
(e)
(1) Routine maintenance, repair, and replacement;
(2) Use of an alternative fuel or raw material by reason of an order under sections 2(a) and (b) of the Energy Supply and Environmental Coordination Act of 1974 (or any superseding legislation) or by reason of a natural gas curtailment plan pursuant to the Federal Power Act;
(3) Use of an alternative fuel by reason of an order or rule under section 125 of the Act;
(4) Use of an alternative fuel at a steam generating unit to the extent that the fuel is generated from municipal solid waste;
(5) Use of an alternative fuel or raw material by a stationary source which the source is approved to use under any permit issued under 40 CFR 52.21 or under regulations approved pursuant to § 51.165 or § 51.166, or which:
(i) For purposes of evaluating attainment pollutants, the source was capable of accommodating before January 6, 1975, unless such change would be prohibited under any federally enforceable permit condition which was established after January 6, 1975 pursuant to 40 CFR 52.21 or under regulations approved pursuant to subpart I of this part; or
(ii) For purposes of evaluating nonattainment pollutants, the source was capable of accommodating before December 21, 1976, unless such change would be prohibited under any federally enforceable permit condition which was established after December 21, 1976 pursuant to 40 CFR 52.21 or under regulations approved pursuant to subpart I of this part;
(6) An increase in the hours of operation or in the production rate, unless such change is prohibited under any federally enforceable permit condition which was established after January 6, 1975 (for purposes of evaluating attainment pollutants) or after December 21, 1976 (for purposes of evaluating nonattainment pollutants) pursuant to 40 CFR 52.21 or regulations approved pursuant to subpart I of this part;
(7) Any change in ownership at a stationary source;
(8) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project, provided that the project complies with:
(i) The State Implementation Plan for the State in which the project is located; and
(ii) Other requirements necessary to attain and maintain the national ambient air quality standard during the project and after it is terminated;
(9) For purposes of evaluating attainment pollutants, the installation or operation of a permanent clean coal technology demonstration project that constitutes repowering, provided that the project does not result in an increase in the potential to emit of any regulated pollutant emitted by the unit. This exemption shall apply on a pollutant-by-pollutant basis; or
(10) For purposes of evaluating attainment pollutants, the reactivation of a very clean coal-fired EGU.
(f)
(1)
(i)
(A) Select a period of 365 consecutive days within the 5-year period
(B) Delete any unacceptable hourly data from this 365-day period in accordance with the data limitations in paragraph (f)(2) of this section.
(C) Extract the hourly data for the 10 percent of the remaining data set corresponding to the highest heat input rates for the selected period. This step may be facilitated by sorting the data set for the remaining operating hours from the lowest to the highest heat input rates.
(D) Calculate the average emissions rate from the extracted (
(E) Calculate the standard deviation of the data set using Equation 2:
(F) Calculate the Upper Tolerance Limit of the data set using Equation 3:
(G) Use the UTL calculated in paragraph (f)(1)(i)(F) of this section as the pre-change maximum actual hourly emissions rate.
(ii)
(iii)
(1)
(i)
(ii)
(A) Continuous emissions monitoring system (CEMS).
(B) Approved predictive emissions monitoring system (PEMS).
(C) Emission tests/emission factor specific to the EGU to be changed.
(D) Material balance calculations.
(E) Published emission factor.
(iii)
(iv)
(1)
(2)
(i)
(B) You must not use continuous emissions monitoring system (CEMS) or predictive emissions monitoring system (PEMS) data recorded during monitoring system out-of-control periods. Out-of-control periods include those during which the monitoring system fails to meet quality assurance criteria (for example, periods of system breakdown, repair, calibration checks, or zero and span adjustments) established by regulation, by permit, or in an approved quality assurance plan.
(C) You must not use emissions rate data from periods of noncompliance when your EGU was operating above an emission limitation that was legally enforceable at the time the data were collected.
(D) You must not use data from any period for which the information is inadequate for determining emissions rates, including information related to the limitations in paragraphs (f)(2)(i)(A) through (C) of this section.
(ii)
(B) You must not use continuous emissions monitoring system (CEMS) or predictive emissions monitoring system (PEMS) data recorded during monitoring system out-of-control periods. Out-of-control periods include those during which the monitoring system fails to meet quality assurance criteria (for example, periods of system breakdown, repair, calibration checks, or zero and span adjustments) established by regulation, by permit, or in an approved quality assurance plan.
(C) You must not use data from any period for which the information is inadequate for determining emissions rates, including information related to the limitations in paragraphs (f)(2)(ii)(A) and (B) of this section.
(g)
(1) The file must include, but is not limited to, the following information recorded in permanent form suitable for inspection:
(i) Continuous monitoring system, monitoring device, and performance testing measurements;
(ii) All continuous monitoring system performance evaluations;
(iii) All continuous monitoring system or monitoring device calibration checks;
(iv) All adjustments and maintenance performed on these systems or devices; and
(v) All other information relevant to any determination made under this section of whether a change to an EGU is a modification.
(2) You must retain the file until the later of:
(i) The date 5 years following the date the EGU resumes regular operation after the physical or operational change; and
(ii) The date 5 years following the date of such measurements, maintenance, reports, and records.
(h)
42 U.S.C. 7401
(a)
(b)
(c)
(d)
(1)
(2)
(e)
(1) Routine maintenance, repair, and replacement;
(2) Use of an alternative fuel or raw material by reason of an order under sections 2(a) and (b) of the Energy Supply and Environmental Coordination Act of 1974 (or any superseding legislation) or by reason of a natural gas curtailment plan pursuant to the Federal Power Act;
(3) Use of an alternative fuel by reason of an order or rule under section 125 of the Act;
(4) Use of an alternative fuel at a steam generating unit to the extent that the fuel is generated from municipal solid waste;
(5) Use of an alternative fuel or raw material by a stationary source which the source is approved to use under any permit issued under 40 CFR 52.21 or under regulations approved pursuant to § 51.166 of this chapter, or which the source was capable of accommodating before January 6, 1975, unless such change would be prohibited under any federally enforceable permit condition which was established after January 6, 1975 pursuant to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR part 51, subpart I; or
(6) An increase in the hours of operation or in the production rate, unless such change is prohibited under any federally enforceable permit condition which was established after January 6, 1975 pursuant to 40 CFR 52.21 or regulations approved pursuant to 40 CFR part 51, subpart I;
(7) Any change in ownership at a stationary source;
(8) The installation, operation, cessation, or removal of a temporary clean coal technology demonstration project, provided that the project complies with:
(i) The State Implementation Plan for the State in which the project is located; and
(ii) Other requirements necessary to attain and maintain the national ambient air quality standard during the project and after it is terminated;
(9) For purposes of evaluating attainment pollutants, the installation or operation of a permanent clean coal technology demonstration project that constitutes repowering, provided that the project does not result in an increase in the potential to emit of any regulated pollutant emitted by the unit. This exemption shall apply on a pollutant-by-pollutant basis; or
(10) For purposes of evaluating attainment pollutants, the reactivation of a very clean coal-fired EGU.
(f)
(1)
(i)
(A) Select a period of 365 consecutive days within the 5-year period immediately preceding when you begin actual construction of the physical or operational change. Compile a data set (for example, in a spreadsheet) with the hourly average CEMS or PEMS (as applicable) measured emissions rates and corresponding heat input data for all of the hours of operation for that 365-day period for the pollutant of interest.
(B) Delete any unacceptable hourly data from this 365-day period in accordance with the data limitations in paragraph (f)(2) of this section.
(C) Extract the hourly data for the 10 percent of the remaining data set corresponding to the highest heat input rates for the selected period. This step may be facilitated by sorting the data set for the remaining operating hours from the lowest to the highest heat input rates.
(D) Calculate the average emissions rate from the extracted (
(E) Calculate the standard deviation of the data set using Equation 2:
(F) Calculate the Upper Tolerance Limit of the data set using Equation 3:
(G) Use the UTL calculated in paragraph (f)(1)(i)(F) of this section as the pre-change maximum actual hourly emissions rate.
(ii)
(iii)
(1)
(i)
(ii)
(A) Continuous emissions monitoring system (CEMS).
(B) Approved predictive emissions monitoring system (PEMS).
(C) Emission tests/emission factor specific to the EGU to be changed.
(D) Material balance calculations.
(E) Published emission factor.
(iii)
(iv)
(1)
(2)
(i)
(B) You must not use continuous emissions monitoring system (CEMS) or predictive emissions monitoring system (PEMS) data recorded during monitoring system out-of-control periods. Out-of-control periods include those during which the monitoring system fails to meet quality assurance criteria (for example, periods of system breakdown, repair, calibration checks, or zero and span adjustments) established by regulation, by permit, or in an approved quality assurance plan.
(C) You must not use emissions rate data from periods of noncompliance when your EGU was operating above an emission limitation that was legally enforceable at the time the data were collected.
(D) You must not use data from any period for which the information is inadequate for determining emissions rates, including information related to the limitations in paragraphs (f)(2)(i)(A) through (C) of this section.
(ii)
(B) You must not use continuous emissions monitoring system (CEMS) or predictive emissions monitoring system (PEMS) data recorded during monitoring system out-of-control periods. Out-of-control periods include those during which the monitoring system fails to meet quality assurance criteria (for example, periods of system breakdown, repair, calibration checks, or zero and span adjustments) established by regulation, by permit, or in an approved quality assurance plan.
(C) You must not use data from any period for which the information is inadequate for determining emissions rates, including information related to the limitations in paragraphs (f)(2)(ii)(A) and (B) of this section.
(g)
(1) The file must include, but is not limited to, the following information recorded in permanent form suitable for inspection:
(i) Continuous monitoring system, monitoring device, and performance testing measurements;
(ii) All continuous monitoring system performance evaluations;
(iii) All continuous monitoring system or monitoring device calibration checks;
(iv) All adjustments and maintenance performed on these systems or devices; and
(v) All other information relevant to any determination made under this section of whether a change to an EGU is a modification.
(2) You must retain the file until the later of:
(i) The date 5 years following the date the EGU resumes regular operation after the physical or operational change; and
(ii) The date 5 years following the date of such measurements, maintenance, reports, and records.
(h)
42 U.S.C. 7401
(a) The provisions of this subpart apply to States upon publication of a final emission guideline under § 60.22a(a), if such final guideline is published after [date of publication of final rule in the
(1) Each emission guideline promulgated under this part is subject to the requirements of this subpart, except that each emission guideline may include specific provisions in addition to or that supersede requirements of this subpart. Each emission guideline must identify explicitly any provision of this subpart that is superseded.
(2) Terms used throughout this part are defined in § 60.21a or in the Clean Air Act (Act) as amended in 1990, except that emission guidelines promulgated as individual subparts of this part may include specific definitions in addition to or that supersede definitions in § 60.21a.
(b) No standard of performance or other requirement established under this part shall be interpreted, construed, or applied to diminish or replace the requirements of a more stringent emission limitation or other applicable requirement established by the Administrator pursuant to other authority of the Act (section 112, Part C or D, or any other authority of the Act), or a standard issued under State authority. The Administrator may specify in a specific standard under this part that facilities subject to other provisions under the Act need only comply with the provisions of that standard.
Terms used but not defined in this subpart shall have the meaning given them in the Act and in subpart A:
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(1) Submittal of a final control plan for the designated facility to the appropriate air pollution control agency;
(2) Awarding of contracts for emission control systems or for process modifications, or issuance of orders for the purchase of component parts to accomplish emission control or process modification;
(3) Initiation of on-site construction or installation of emission control equipment or process change;
(4) Completion of on-site construction or installation of emission control equipment or process change; and
(5) Final compliance.
(i)
(j)
(a) Concurrently upon or after proposal of standards of performance for the control of a designated pollutant from affected facilities, the Administrator will publish a draft emission guideline containing information pertinent to control of the designated pollutant from designated facilities. Notice of the availability of the draft emission guideline will be published in the
(b) Emission guidelines published under this section will provide information for the development of State plans, such as:
(1) A description of systems of emission reduction which, in the judgment of the Administrator, have been adequately demonstrated.
(2) Information on the degree of emission reduction which is achievable with each system, together with information on the costs, nonair quality health environmental effects, and energy requirements of applying each system to designated facilities.
(3) Incremental periods of time normally expected to be necessary for the design, installation, and startup of identified control systems.
(4) An emission guideline that reflects the application of the best system of emission reduction (considering the cost of such achieving reduction and any nonair quality health and environmental impact and energy requirements) that has been adequately demonstrated for designated facilities, and the time within which compliance with standards of performance can be achieved. The Administrator may specify different emission guidelines or compliance times or both for different sizes, types, and classes of designated facilities when costs of control, physical limitations, geographical location, or similar factors make subcategorization appropriate.
(5) Such other available information as the Administrator determines may contribute to the formulation of State plans.
(a)(1) Unless otherwise specified in the applicable subpart, within three years after notice of the availability of a final emission guideline is published under § 60.22a(a), each State shall adopt and submit to the Administrator, in accordance with § 60.4, a plan for the control of the designated pollutant to which the emission guideline applies.
(2) At any time, each State may adopt and submit to the Administrator any plan revision necessary to meet the requirements of this subpart or an applicable subpart of this part.
(b) If no designated facility is located within a State, the State shall submit a letter of certification to that effect to the Administrator within the time specified in paragraph (a) of this section. Such certification shall exempt the State from the requirements of this subpart for that designated pollutant.
(c) The State shall, prior to the adoption of any plan or revision thereof, conduct one or more public hearings within the State on such plan or plan revision.
(d) Any hearing required by paragraph (c) of this section shall be held only after reasonable notice. Notice shall be given at least 30 days prior to the date of such hearing and shall include:
(1) Notification to the public by prominently advertising the date, time, and place of such hearing in each region affected. This requirement may be satisfied by advertisement on the internet;
(2) Availability, at the time of public announcement, of each proposed plan or revision thereof for public inspection in at least one location in each region to which it will apply. This requirement may be satisfied by posting each proposed plan or revision on the internet;
(3) Notification to the Administrator;
(4) Notification to each local air pollution control agency in each region to which the plan or revision will apply; and
(5) In the case of an interstate region, notification to any other State included in the region.
(e) The State may cancel the public hearing through a method it identifies if no request for a public hearing is received during the 30 day notification period under subsection (d) and the original notice announcing the 30 day notification period states that if no request for a public hearing is received the hearing will be cancelled; identifies the method and time for announcing that the hearing has been cancelled; and provides a contact phone number for the public to call to find out if the hearing has been cancelled.
(f) The State shall prepare and retain, for a minimum of 2 years, a record of each hearing for inspection by any interested party. The record shall contain, as a minimum, a list of witnesses together with the text of each presentation.
(g) The State shall submit with the plan or revision:
(1) Certification that each hearing required by paragraph (c) of this section was held in accordance with the notice required by paragraph (d) of this section; and
(2) A list of witnesses and their organizational affiliations, if any, appearing at the hearing and a brief written summary of each presentation or written submission.
(h) Upon written application by a State agency (through the appropriate Regional Office), the Administrator may approve State procedures designed to insure public participation in the matters for which hearings are required and public notification of the opportunity to participate if, in the judgment of the Administrator, the procedures, although different from the requirements of this subpart, in fact provide for adequate notice to and participation of the public. The Administrator may impose such conditions on his approval as he deems necessary. Procedures approved under this section shall be deemed to satisfy the requirements of this subpart regarding procedures for public hearings.
(a) Each plan shall include standards of performance and compliance schedules.
(b) Standards of performance shall either be based on allowable rate or limit of emissions, except when it is not feasible to prescribe or enforce a standard of performance. The EPA shall identify such cases in the emission guidelines issued under § 60.22a. Where standards of performance prescribing design, equipment, work practice, or operational standard, or combination thereof are established, the plan shall, to the degree possible, set forth the emission reductions achievable by implementation of such standards, and may permit compliance by the use of equipment determined by the State to be equivalent to that prescribed.
(1) Test methods and procedures for determining compliance with the standards of performance shall be specified in the plan. Methods other than those specified in appendix A to this part or an applicable subpart of this part may be specified in the plan if shown to be equivalent or alternative methods as defined in § 60.2(t) and (u).
(2) Standards of performance shall apply to all designated facilities within the State. A plan may contain standards of performance adopted by local jurisdictions provided that the standards are enforceable by the State.
(c) Except as provided in paragraph (e) of this section, standards of performance shall be no less stringent than the corresponding emission guideline(s) specified in subpart C of this part, and final compliance shall be required as expeditiously as practicable, but no later than the compliance times specified in an applicable subpart of this part.
(d)(1) Any compliance schedule extending more than 24 months from the date required for submittal of the plan must include legally enforceable increments of progress to achieve compliance for each designated facility or category of facilities. Unless otherwise specified in the applicable subpart, increments of progress must include, where practicable, each increment of progress specified in § 60.21a(h) and must include such additional increments of progress as may be necessary to permit close and effective supervision of progress toward final compliance.
(2) A plan may provide that compliance schedules for individual sources or categories of sources will be formulated after plan submittal. Any such schedule shall be the subject of a public hearing held according to § 60.23a and shall be submitted to the Administrator within 60 days after the date of adoption of the schedule but in no case later than the date prescribed for submittal of the first semiannual report required by § 60.25a(e).
(e) In applying a standard of performance to a particular source, the State may take into consideration factors, such as the remaining useful life of such source, provided that the State demonstrates with respect to each such facility (or class of such facilities):
(1) Unreasonable cost of control resulting from plant age, location, or basic process design;
(2) Physical impossibility of installing necessary control equipment; or
(3) Other factors specific to the facility (or class of facilities) that make application of a less stringent standard or final compliance time significantly more reasonable.
(f) Nothing in this subpart shall be construed to preclude any State or political subdivision thereof from adopting or enforcing:
(1) Standards of performance more stringent than emission guidelines specified in subpart C of this part or in applicable emission guidelines; or
(2) Compliance schedules requiring final compliance at earlier times than those specified in subpart C or in applicable emission guidelines.
(a) Each plan shall include an inventory of all designated facilities, including emission data for the designated pollutants and information related to emissions as specified in appendix D to this part. Such data shall be summarized in the plan, and emission rates of designated pollutants from designated facilities shall be correlated with applicable standards of performance. As used in this subpart, “correlated” means presented in such a manner as to show the relationship between measured or estimated amounts of emissions and the amounts of such emissions allowable under applicable standards of performance.
(b) Each plan shall provide for monitoring the status of compliance with applicable standards of performance. Each plan shall, as a minimum, provide for:
(1) Legally enforceable procedures for requiring owners or operators of designated facilities to maintain records and periodically report to the State information on the nature and amount of emissions from such facilities, and/or such other information as may be necessary to enable the State to determine whether such facilities are in compliance with applicable portions of the plan. Submission of electronic documents shall comply with the requirements of 40 CFR part 3—(Electronic reporting).
(2) Periodic inspection and, when applicable, testing of designated facilities.
(c) Each plan shall provide that information obtained by the State under paragraph (b) of this section shall be
(d) The provisions referred to in paragraphs (b) and (c) of this section shall be specifically identified. Copies of such provisions shall be submitted with the plan unless:
(1) They have been approved as portions of a preceding plan submitted under this subpart or as portions of an implementation plan submitted under section 110 of the Act, and
(2) The State demonstrates:
(i) That the provisions are applicable to the designated pollutant(s) for which the plan is submitted, and
(ii) That the requirements of § 60.26a are met.
(e) The State shall submit reports on progress in plan enforcement to the Administrator on an annual (calendar year) basis, commencing with the first full report period after approval of a plan or after promulgation of a plan by the Administrator. Information required under this paragraph must be included in the annual report required by § 51.321 of this chapter.
(f) Each progress report shall include:
(1) Enforcement actions initiated against designated facilities during the reporting period, under any standard of performance or compliance schedule of the plan.
(2) Identification of the achievement of any increment of progress required by the applicable plan during the reporting period.
(3) Identification of designated facilities that have ceased operation during the reporting period.
(4) Submission of emission inventory data as described in paragraph (a) of this section for designated facilities that were not in operation at the time of plan development but began operation during the reporting period.
(5) Submission of additional data as necessary to update the information submitted under paragraph (a) of this section or in previous progress reports.
(6) Submission of copies of technical reports on all performance testing on designated facilities conducted under paragraph (b)(2) of this section, complete with concurrently recorded process data.
(a) Each plan shall show that the State has legal authority to carry out the plan, including authority to:
(1) Adopt standards of performance and compliance schedules applicable to designated facilities.
(2) Enforce applicable laws, regulations, standards, and compliance schedules, and seek injunctive relief.
(3) Obtain information necessary to determine whether designated facilities are in compliance with applicable laws, regulations, standards, and compliance schedules, including authority to require recordkeeping and to make inspections and conduct tests of designated facilities.
(4) Require owners or operators of designated facilities to install, maintain, and use emission monitoring devices and to make periodic reports to the State on the nature and amounts of emissions from such facilities; also authority for the State to make such data available to the public as reported and as correlated with applicable standards of performance.
(b) The provisions of law or regulations which the State determines provide the authorities required by this section shall be specifically identified. Copies of such laws or regulations shall be submitted with the plan unless:
(1) They have been approved as portions of a preceding plan submitted under this subpart or as portions of an implementation plan submitted under section 110 of the Act, and
(2) The State demonstrates that the laws or regulations are applicable to the designated pollutant(s) for which the plan is submitted.
(c) The plan shall show that the legal authorities specified in this section are available to the State at the time of submission of the plan. Legal authority adequate to meet the requirements of paragraphs (a)(3) and (4) of this section may be delegated to the State under section 114 of the Act.
(d) A State governmental agency other than the State air pollution control agency may be assigned responsibility for carrying out a portion of a plan if the plan demonstrates to the Administrator's satisfaction that the State governmental agency has the legal authority necessary to carry out that portion of the plan.
(e) The State may authorize a local agency to carry out a plan, or portion thereof, within the local agency's jurisdiction if the plan demonstrates to the Administrator's satisfaction that the local agency has the legal authority necessary to implement the plan or portion thereof, and that the authorization does not relieve the State of responsibility under the Act for carrying out the plan or portion thereof.
(a) The Administrator may, whenever he determines necessary, shorten the period for submission of any plan or plan revision or portion thereof.
(b) After determination that a plan or plan revision is complete per the requirements of paragraph (g) of this section, the Administrator will take action on the plan or revision. The Administrator will, within twelve months of finding that a plan or plan revision is complete, approve or disapprove such plan or revision or each portion thereof.
(c) The Administrator will propose to promulgate, through notice and comment rulemaking, a federal plan, or portion thereof, for a State if:
(1) The Administrator finds that a State fails to submit a required complete plan or complete plan revision within the time prescribed; or
(2) The Administrator disapproves the required State plan or plan revision or any portion thereof, as unsatisfactory because the applicable requirements of this subpart or an applicable subpart under this part have not been met.
(d) The Administrator will, at any time within two years after the finding of failure to submit a complete plan or disapproval described under paragraph (c) of this section, promulgate a final federal plan unless, prior to such promulgation, the State has adopted and submitted a plan or plan revision which the Administrator determines to be approvable.
(e)(1) Except as provided in paragraph (e)(2) of this section, a federal plan promulgated by the Administrator under this section will prescribe standards of performance of the same stringency as the corresponding emission guideline(s) specified in the final emission guideline published under § 60.22a(a) and will require compliance with such standards as expeditiously as practicable but no later than the times specified in the emission guideline.
(2) Upon application by the owner or operator of a designated facility to which regulations proposed and promulgated under this section will apply, the Administrator may provide for the application of less stringent standards of performance or longer compliance schedules than those otherwise required by this section in accordance with the criteria specified in § 60.24a(f).
(f) Prior to promulgation of a federal plan under paragraph (d) of this section, the Administrator will provide the opportunity for at least one public hearing in either:
(1) Each State that failed to hold a public hearing as required by § 60.23a(c); or
(2) Washington, DC or an alternate location specified in the
(g) Each plan or plan revision that is submitted to the Administrator shall be
(1)
(2)
(i) A formal letter of submittal from the Governor or her designee requesting EPA approval of the plan or revision thereof;
(ii) Evidence that the State has adopted the plan in the state code or body of regulations. That evidence must include the date of adoption or final issuance as well as the effective date of the plan, if different from the adoption/issuance date;
(iii) Evidence that the State has the necessary legal authority under state law to adopt and implement the plan;
(iv) A copy of the actual regulation, or document submitted for approval and incorporation by reference into the plan. The submittal must be a copy of the official state regulation or document signed, stamped and dated by the appropriate state official indicating that it is fully enforceable by the State. The effective date of the regulation or document must, whenever possible, be indicated in the document itself. The State's electronic copy must be an exact duplicate of the hard copy. For revisions to the approved plan, the submittal must indicate the changes made (for example, by redline/strikethrough) to the approved plan;
(v) Evidence that the State followed all of the procedural requirements of the state's laws and constitution in conducting and completing the adoption and issuance of the plan;
(vi) Evidence that public notice was given of the proposed change with procedures consistent with the requirements of § 60.23, including the date of publication of such notice;
(vii) Certification that public hearing(s) were held in accordance with the information provided in the public notice and the State's laws and constitution, if applicable and consistent with the public hearing requirements in § 60.23;
(viii) Compilation of public comments and the State's response thereto; and
(ix) Such other criteria for completeness as may be specified by the Administrator under the applicable emission guidelines.
(3)
(i) Description of the plan approach and geographic scope;
(ii) Identification of each affected source, identification of emission standards for the affected sources, and monitoring, recordkeeping and reporting requirements that will determine compliance by each affected source;
(iii) Identification of compliance schedules and/or increments of progress;
(iv) Demonstration that the State plan submittal is projected to achieve emissions performance under the applicable emission guidelines;
(v) Documentation of state recordkeeping and reporting requirements to determine the performance of the plan as a whole; and
(vi) Demonstration that each emission standard is quantifiable, non-duplicative, permanent, verifiable, and enforceable.
(a) Plan revisions shall be submitted to the Administrator within 12 months, or shorter if required by the Administrator, after notice of the availability of a final revised emission guideline is published under § 60.22a, in accordance with the procedures and requirements applicable to development and submission of the original plan.
(b) A revision of a plan, or any portion thereof, shall not be considered part of an applicable plan until approved by the Administrator in accordance with this subpart.
After notice and opportunity for public hearing in each affected State, the Administrator may revise any provision of an applicable federal plan if:
(a) The provision was promulgated by the Administrator, and
(b) The plan, as revised, will be consistent with the Act and with the requirements of this subpart.
This subpart establishes emission guidelines and approval criteria for State plans that establish standards of performance limiting greenhouse gas (GHG) emissions from an affected steam generating unit. An affected steam generating unit for the purposes of this subpart, is referred to as an affected EGU. These emission guidelines are developed in accordance with section 111(d) of the Clean Air Act and subpart Ba of this part. To the extent any requirement of this subpart is inconsistent with the requirements of subparts A or subpart Ba of this part, the requirements of this subpart will apply.
(a) The pollutants regulated by this subpart are greenhouse gases. The emission guidelines for greenhouse gases established in this subpart are heat rate improvements which target achieving lower carbon dioxide (CO
(b) PSD and Title V thresholds for greenhouse gases are set out in this paragraph (b).
(1) For the purposes of § 51.166(b)(49)(ii), with respect to GHG emissions from facilities, the “pollutant that is subject to the standard promulgated under section 111 of the Act” shall be considered to be the pollutant that otherwise is subject to regulation under the Act as defined in § 51.166(b)(48) and in any State Implementation Plan (SIP) approved by the EPA that is interpreted to incorporate, or specifically incorporates, § 51.166(b)(48) of this chapter.
(2) For the purposes of § 52.21(b)(50)(ii), with respect to GHG emissions from facilities regulated in the plan, the “pollutant that is subject to the standard promulgated under section 111 of the Act” shall be considered to be the pollutant that otherwise is subject to regulation under the Act as defined in § 52.21(b)(49) of this chapter.
(3) For the purposes of § 70.2 of this chapter, with respect to greenhouse gas emissions from facilities regulated in the plan, the “pollutant that is subject to any standard promulgated under section 111 of the Act” shall be considered to be the pollutant that otherwise is “subject to regulation” as defined in § 70.2 of this chapter.
(4) For the purposes of § 71.2, with respect to greenhouse gas emissions from facilities regulated in the plan, the “pollutant that is subject to any standard promulgated under section 111 of the Act” shall be considered to be the pollutant that otherwise is “subject to regulation” as defined in § 71.2 of this chapter.
If you are the Governor of a State in the contiguous United States with one or more affected EGUs that commenced construction on or before August 31, 2018, you are subject to this action and you must submit a State plan to the U.S. Environmental Protection Agency (EPA) that implements the emission guidelines contained in this subpart. If you are the Governor of a State in the United States with no affected EGUs for which construction commenced on or before August 31, 2018, in your State, you must submit a negative declaration letter in place of the State plan.
The EPA will review your plan according to § 60.27a to approve or disapprove such plan or revision or each portion thereof.
(a) If you do not submit an approvable plan the EPA will develop a Federal plan for your State according to § 60.27a. The Federal plan will implement the emission guidelines contained in this subpart. Owners and operators of affected EGUs not covered by an approved plan must comply with a Federal plan implemented by the EPA for the State.
(b) After a Federal plan has been implemented in your State, it will be withdrawn when your State submits, and the EPA approves, a plan.
A State may meet its CAA section 111(d) obligations only by submitting a State plan submittal or a negative declaration letter (if applicable).
The EPA has no formal review process for negative declaration letters. Once your negative declaration letter has been received, the EPA will place a copy in the public docket and publish a notice in the
(a) You must include the components described in paragraphs (a)(1) through (4) of this section in your plan submittal. The final plan must meet the requirements of, and include the information required under, § 60.5740a.
(1)
(2)
(3)
(4)
(b) You must follow the requirements of subpart Ba of this part and demonstrate that they were met in your State plan.
(a) In addition to the components of the plan listed in § 60.5735a, a state plan submittal to the EPA must include the information in paragraphs (a)(1) through (8) of this section. This information must be submitted to the EPA as part of your plan submittal but
(1) You must include a summary of how you determined each standard of performance for each affected EGU according to § 60.5755a(a). You must include in the summary an evaluation of the applicability of each of the following heat rate improvements to each affected EGU:
(i) Neural network/intelligent sootblowers
(ii) Boiler feed pumps
(iii) Air heater and duct leakage control
(iv) Variable frequency drives
(v) Blade path upgrades for steam turbines
(vi) Redesign or replacement of economizer
(vii) Improved operating and maintenance practices
(2) In applying a standard of performance, if you consider remaining useful life and other factors for an affected EGU as provided in § 60.24a(e), you must include a summary of the application of the relevant factors in deriving a standard of performance.
(3) You must include a demonstration that each affected EGU's standard of performance is quantifiable, non-duplicative, permanent, verifiable, and enforceable according to § 60.5755a.
(4) Your plan demonstration, if applicable, must include the information listed in paragraphs (a)(4)(i) through (v) of this section as applicable.
(i) A summary of each affected EGU's anticipated future operation characteristics, including:
(A) Annual generation;
(B) CO
(C) Fuel use, fuel prices (when applicable), fuel carbon content;
(D) Fixed and variable operations and maintenance costs (when applicable);
(E) Heat rates; and
(F) Electric generation capacity and capacity factors.
(ii) A timeline for implementation of EGU-specific actions (if applicable).
(iii) All wholesale electricity prices.
(iv) A time period of analysis, which must extend through at least 2035.
(v) A demonstration that each standard of performance included in your plan meets the requirements of § 60.5755a.
(5) Your plan submittal must include a timeline with all the programmatic milestone steps the State intends to take between the time of the State plan submittal and [date three years after the notice of availability of a final emission guideline is published in the
(6) Your plan submittal must adequately demonstrate that your State has the legal authority (
(7) Your plan submittal must include certification that a hearing required under § 60.23a(c)on the State plan was held, a list of witnesses and their organizational affiliations, if any, appearing at the hearing, and a brief written summary of each presentation or written submission, pursuant to the requirements of § 60.27a(f).
(8) Your plan submittal must include supporting material for your plan including:
(i) Materials demonstrating the State's legal authority to implement and enforce each component of its plan, including standards of performance, pursuant to the requirements of § 60.27a(f) and § 60.5740a(a)(6);
(ii) Materials supporting calculations for affected EGU's standards of performance according to § 60.5755a; and
(iii) Any other materials necessary to support evaluation of the plan by the EPA.
(b) You must submit your final plan to the EPA electronically according to § 60.5800a.
You must submit a plan with the information required under § 60.5740a by [date three years after the notice of availability of a final emission guideline is published in the
The standards of performance for affected EGUs regulated under the plan must include compliance periods. Any compliance period extending more than 24 months from the date required for submittal of the plan must include legally enforceable increments of progress to achieve compliance for each designated facility or category of facilities.
(a) You must set a standard of performance for each affected EGU within the state.
(1) The standard of performance must be an emission performance rate relating mass of CO
(2) In establishing any standard of performance, you must consider the applicability of each of the heat rate improvements included in § 60.5740a(1) to the affected EGU.
(i) In applying a standard of performance to any affected EGU, you may consider the source-specific factors included in § 60.24(e).
(ii) If you consider source-specific factors to apply a standard of performance, you must include a demonstration in your plan submission for how you considered such factors.
(b) Standards of performance for affected EGUs included under your plan must be demonstrated to be quantifiable, verifiable, non-duplicative, permanent, and enforceable with respect to each affected EGU. The plan submittal must include the methods by which each standard of performance meets each of the requirements in paragraphs (c) through (f) of this section.
(c) An affected EGU's standard of performance is quantifiable if it can be reliably measured in a manner that can be replicated.
(d) An affected EGU's standard of performance is verifiable if adequate monitoring, recordkeeping and reporting requirements are in place to enable the State and the Administrator to independently evaluate, measure, and verify compliance with the standard of performance.
(e) An affected EGU's standard of performance is permanent if the standard of performance must be met for each compliance period, unless it is replaced by another standard of performance in an approved plan revision.
(f) An affected EGU's standard of performance is enforceable if:
(1) A technically accurate limitation or requirement and the time period for the limitation or requirement are specified;
(2) Compliance requirements are clearly defined;
(3) The affected EGU responsible for compliance and liable for violations can be identified;
(4) Each compliance activity or measure is enforceable as a practical matter; and
(5) The Administrator, the State, and third parties maintain the ability to enforce against violations (including if an affected EGU does not meet its standard of performance based on its emissions) and secure appropriate corrective actions, in the case of the Administrator pursuant to CAA sections 113(a)-(h), in the case of a State, pursuant to its plan, State law or CAA section 304, as applicable, and in the
EPA-approved plans can be revised only with approval by the Administrator. The Administrator will approve a plan revision if it is satisfactory with respect to the applicable requirements of this subpart and any applicable requirements of subpart Ba of this part, including the requirements in § 60.5740a. If one (or more) of the elements of the plan set in § 60.5735a require revision, a request must be submitted to the Administrator indicating the proposed revisions to the plan to ensure the CO
To meet your plan obligations, you must demonstrate that your affected EGUs are complying with their standards of performance as specified in § 60.5755a.
(a) This subpart does not directly affect EGU owners or operators in your State. However, affected EGU owners or operators must comply with the plan that a State develops to implement the emission guidelines contained in this subpart.
(b) If a State does not submit a plan to implement and enforce the emission guidelines contained in this subpart by [date three years after the notice of availability of a final emission guideline is published in the
(a) The EGUs that must be addressed by your plan are any affected EGU that commenced construction on or before August 31, 2018.
(b) An affected EGU is a steam generating unit that meets the relevant applicability conditions specified in paragraph (b)(1) through (2), as applicable, of this section except as provided in § 60.5780a.
(1) Serves a generator connected to a utility power distribution system with a nameplate capacity greater than 25 MW-net (
(2) Has a base load rating (
(a) An EGU that is excluded from being an affected EGU is:
(1) An EGU that is subject to subpart TTTT of this part as a result of commencing construction, reconstruction or modification after the subpart TTTT applicability date;
(2) A steam generating unit that is, and always has been, subject to a federally enforceable permit limiting annual net-electric sales to one-third or less of its potential electric output, or 219,000 MWh or less;
(3) A stationary combustion turbine that meets the definition of either a combined cycle or combined heat and power combustion turbine;
(4) An IGCC unit;
(5) A non-fossil unit (
(6) An EGU that is a combined heat and power unit that has always limited, or is subject to a federally enforceable permit limiting, annual net-electric sales to a utility distribution system to no more than the greater of either 219,000 MWh or the product of the design efficiency and the potential electric output;
(7) An EGU that serves a generator along with other steam generating unit(s), IGCC(s), or stationary combustion turbine(s) where the effective generation capacity (determined based on a prorated output of the base load rating of each steam generating unit, IGCC, or stationary combustion turbine) is 25 MW or less;
(8) An EGU that is a municipal waste combustor unit that is subject to subpart Eb of this part; or
(9) An EGU that is a commercial or industrial solid waste incineration unit that is subject to subpart CCCC of this part.
(b) [Reserved]
(a) Your plan must include monitoring, recordkeeping, and reporting requirements for affected EGUs. To satisfy this requirement, you have the option of either:
(1) Specifying that sources must report emission and electricity generation data according to part 75 of this chapter; or
(2) Describing an alternative monitoring, recordkeeping, and reporting program that includes specifications for the following program elements:
(i) Monitoring plans that specify the monitoring methods, systems, and formulas that will be used to measure CO
(ii) Monitoring methods to continuously and accurately measure all CO
(iii) Quality assurance test requirements to ensure monitoring systems provide reliable and accurate data for assessing and verifying compliance;
(iv) Recordkeeping requirements;
(v) Electronic reporting procedures and systems; and
(vi) Data validation procedures for ensuring data are complete and calculated consistent with program rules, including procedures for determining substitute data in instances where required data would otherwise be incomplete.
(b) [Reserved]
(a) You must keep records of all information relied upon in support of any demonstration of plan components, plan requirements, supporting documentation, and the status of meeting the plan requirements defined in the plan for each interim step and the interim period. After [date plan takes effect], States must keep records of all information relied upon in support of any continued demonstration that the final CO
(b) You must keep records of all data submitted by the owner or operator of each affected EGU that is used to determine compliance with each affected EGU emissions standard or requirements in an approved State plan, consistent with the affected EGU requirements listed in § 60.5785a.
(c) If your State has a requirement for all hourly CO
(d) You must keep records at a minimum for 5 years from the date the record is used to determine compliance with a standard of performance or plan requirement. Each record must be in a form suitable and readily available for expeditious review.
You must submit an annual report as required under § 60.25a(e) and (f).
(a) You must submit to the EPA the information required by the emission guidelines in this subpart following the procedures in paragraphs (b) through (e) of this section.
(b) All negative declarations, State plan submittals, supporting materials that are part of a State plan submittal, any plan revisions, and all State reports required to be submitted to the EPA by the State plan must be reported through EPA's State Plan Electronic Collection System (SPeCS). SPeCS is a web accessible electronic system accessed at the EPA's Central Data Exchange (CDX) (
(c) Only a submittal by the Governor or the Governor's designee by an electronic submission through SPeCS shall be considered an official submittal to the EPA under this subpart. If the Governor wishes to designate another responsible official the authority to submit a State plan, the EPA must be notified via letter from the Governor prior to the [date three years after the notice of availability of a final emission guideline is published in the
(d) The submission of the information by the authorized official must be in a non-editable format. In addition to the non-editable version all plan components designated as federally enforceable must also be submitted in an editable version.
(e) You must provide the EPA with non-editable and editable copies of any submitted revision to existing approved federally enforceable plan components. The editable copy of any such submitted plan revision must indicate the changes made at the State level, if any, to the existing approved federally enforceable plan components, using a mechanism such as redline/strikethrough. These changes are not part of the State plan until formal approval by EPA.
As used in this subpart, all terms not defined herein will have the meaning given them in the Clean Air Act and in subparts TTTT, A (General Provisions) and subpart Ba of this part.
(1) The net electric or mechanical output from the affected facility, plus 100 percent of the useful thermal output measured relative to SATP conditions that is not used to generate additional electric or mechanical output or to enhance the performance of the unit (
(2) For combined heat and power facilities where at least 20.0 percent of the total gross or net energy output consists of electric or direct mechanical output and at least 20.0 percent of the total gross or net energy output consists of useful thermal output on a 12-operating month rolling average basis, the net electric or mechanical output from the affected EGU divided by 0.95, plus 100 percent of the useful thermal output; (
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 |