Page Range | 51935-52172 | |
FR Document |
Page and Subject | |
---|---|
80 FR 52169 - Women's Equality Day, 2015 | |
80 FR 51943 - Safety Zones; Cleveland Dragon Boat Festival and Head of the Cuyahoga, Cuyahoga River, Cleveland, OH | |
80 FR 51942 - Drawbridge Operation Regulation; Sacramento River, Freeport, CA | |
80 FR 52059 - Notice of Public Meeting, Pecos District Resource Advisory Council Meeting, New Mexico | |
80 FR 52060 - Notice of Public Meeting; Central Montana Resource Advisory Council | |
80 FR 52061 - Information Collection Activities: Oil and Gas Production Requirements; Proposed Collection; Comment Request | |
80 FR 52060 - Filing of Plats of Survey: Oregon/Washington | |
80 FR 52050 - Center for Scientific Review; Notice of Closed Meetings | |
80 FR 52051 - Center for Scientific Review; Amended Notice of Meeting | |
80 FR 52036 - Agency Information Collection Activities Under OMB Review | |
80 FR 52038 - Notice Inviting Publishers To Submit Tests for a Determination of Suitability for Use in the National Reporting System for Adult Education | |
80 FR 52051 - Modification of National Customs Automation Program (NCAP) Test Concerning the Submission of Certain Data Required by the Food and Drug Administration (FDA) Using the Partner Government Agency (PGA) Message Set Through the Automated Commercial Environment (ACE) | |
80 FR 52042 - City of River Falls, Wisconsin; Notice of Application Accepted for Filing, Soliciting Comments, Motions To Intervene, and Protests | |
80 FR 52041 - West Valley Water District; Notice of Preliminary Determination of a Qualifying Conduit Hydropower Facility and Soliciting Comments and Motions To Intervene | |
80 FR 52045 - LRI Renewable Energy, LLC; Supplemental Notice That Initial Market-Based Rate Filing Includes Request for Blanket Section 204 Authorization | |
80 FR 52043 - Energy Resources USA Inc.; Notice of Preliminary Permit Application Accepted for Filing and Soliciting Comments, Motions To Intervene, and Competing Applications | |
80 FR 52093 - Proposed Information Collections; Comment Request (No. 55) | |
80 FR 51975 - Residence Rules Involving U.S. Possessions | |
80 FR 52094 - Proposed Collection; Comment Request for Notice 2006-25 | |
80 FR 52095 - Proposed Collection; Comment Request for Revenue Procedure | |
80 FR 51991 - Source Determination for Certain Emission Units in the Oil and Natural Gas Sector; Oil and Natural Gas Sector: Emission Standards for New and Modified Sources; and Review of New Sources and Modifications in Indian Country: Federal Implementation Plan for Managing Air Emissions From True Minor Sources Engaged in Oil and Natural Gas Production in Indian Country | |
80 FR 52029 - Foreign-Trade Zone (FTZ) 154-Baton Rouge, Louisiana; Authorization of Production Activity; Syngenta Crop Protection, LLC; Subzone 154B; (Herbicides and Insecticides), St. Gabriel and Baton Rouge, Louisiana | |
80 FR 52055 - Information Collection Request Sent to the Office of Management and Budget (OMB) for Approval; Policy for Evaluation of Conservation Efforts When Making Listing Decisions (PECE) | |
80 FR 52035 - Agency Information Collection Activities Under OMB Review | |
80 FR 51959 - Atlantic Highly Migratory Species; Atlantic Bluefin Tuna Fisheries | |
80 FR 52031 - Xanthan Gum From the People's Republic of China: Initiation of Antidumping Duty New Shipper Review | |
80 FR 52045 - Agency Forms Undergoing Paperwork Reduction Act Review | |
80 FR 52058 - Filing of Plats of Survey; NV | |
80 FR 52038 - Electric Grid Resilience Self-Assessment Tool for Distribution System | |
80 FR 52039 - Energy Conservation Program for Consumer Products: Representative Average Unit Costs of Energy | |
80 FR 52083 - FTA Supplemental Fiscal Year 2015 Apportionments, Allocations, and Program Information | |
80 FR 52049 - National Institute on Aging; Notice of Closed Meetings | |
80 FR 52050 - National Institute on Aging; Notice of Closed Meeting | |
80 FR 52027 - Deschutes Provinicial Advisory Committee Meeting | |
80 FR 52084 - Pipeline Safety: Request for Revision of a Previously Approved Information Collection: National Pipeline Mapping System Program (OMB Control No. 2137-0596) | |
80 FR 51938 - Medical Devices; Immunology and Microbiology Devices; Classification of Clostridium Difficile Toxin Gene Amplification Assay | |
80 FR 52048 - Determination That BIAXIN XL Oral Tablets Were Not Withdrawn From Sale for Reasons of Safety or Effectiveness | |
80 FR 52047 - Design and Analysis of Shedding Studies for Virus or Bacteria-Based Gene Therapy and Oncolytic Products; Guidance for Industry; Availability | |
80 FR 52056 - Rocky Mountain Arsenal National Wildlife Refuge, Adams County, CO; Environmental Impact Statement | |
80 FR 52067 - Arts Advisory Panel Meetings | |
80 FR 52044 - Combined Notice of Filings | |
80 FR 52044 - Combined Notice of Filings #2 | |
80 FR 52040 - Combined Notice of Filings #1 | |
80 FR 52033 - Atlantic Coastal Fisheries Cooperative Management Act Provisions; American Eel Fishery | |
80 FR 52096 - Privacy Act of 1974: Computer Matching Program | |
80 FR 52049 - National Cancer Institute Amended; Notice of Meeting | |
80 FR 52049 - National Center for Complementary and Integrative Health; Notice of Closed Meeting | |
80 FR 52049 - National Center for Complementary & Integrative Health Notice of Closed Meeting | |
80 FR 52051 - Clinical Center; Notice of Meeting | |
80 FR 52048 - National Institute on Aging; Notice of Meeting | |
80 FR 52081 - Notice of Buy America Waiver for Track Turnout Component | |
80 FR 52079 - Environmental Impact Statement-Closure of CCR Impoundments | |
80 FR 52035 - Marine Mammals; File No. 18636 | |
80 FR 52034 - Marine Mammals; File No. 16239 | |
80 FR 52032 - Proposed Information Collection; Comment Request; Baldrige Executive Fellows Program | |
80 FR 52070 - Self-Regulatory Organizations; CBOE Futures Exchange, LLC; Notice of Proposed Rule Change Regarding Reportable Position and Ownership and Control Reporting Clarifications | |
80 FR 52073 - Self-Regulatory Organizations; NASDAQ OMX PHLX LLC; Notice of Filing and Immediate Effectiveness of Proposed Rule Change To Amend the Options Regulatory Fee | |
80 FR 52075 - Self-Regulatory Organizations; NYSE Arca, Inc.; Notice of Filing and Immediate Effectiveness of Proposed Rule Change Relating to the Use of Derivative Instruments by the SPDR Blackstone/GSO Senior Loan ETF | |
80 FR 52071 - The RBB Fund, Inc. and Abbey Capital Limited; Notice of Application | |
80 FR 52043 - Electric Quarterly Reports: M&R Energy Resources Corp., Reliable Power, LLC, Susterra Energy, LLC; Order on Intent To Revoke Market-Based Rate Authority | |
80 FR 52065 - Agency Information Collection Activities; Submission for OMB Review; Comment Request; Settlement Agreements Between a Plan and a Party in Interest | |
80 FR 51945 - Special Regulations; Areas of the National Park System, Cuyahoga Valley National Park, Bicycling | |
80 FR 52026 - Submission for OMB Review; Comment Request | |
80 FR 51992 - Determinations of Attainment by the Attainment Date, Extensions of the Attainment Date, and Reclassification of Several Areas Classified as Marginal for the 2008 Ozone National Ambient Air Quality Standards | |
80 FR 51963 - Prevailing Rate Systems; Definition of Hancock County, Mississippi, to a Nonappropriated Fund Federal Wage System Wage Area | |
80 FR 52081 - Third Meeting: RTCA Special Committee 233 (SC 233) Addressing Human Factors/Pilot Interface Issues for Avionics | |
80 FR 52029 - Certain Uncoated Paper From Brazil: Preliminary Determination of Sales at Less Than Fair Value and Postponement of Final Determination | |
80 FR 51964 - Low-Level Radioactive Waste Disposal | |
80 FR 51942 - Drawbridge Operation Regulation; Gallants Channel, Beaufort, NC | |
80 FR 52046 - National Center for Health Statistics (NCHS), Classifications and Public Health Data Standards Staff; Meeting | |
80 FR 52066 - Agency Information Collection Activities; Proposed Collection | |
80 FR 52064 - APEC List of Environmental Goods: Advice on the Probable Economic Effect of Providing Duty Reductions for Imports | |
80 FR 52067 - Inservice Inspection of Ungrouted Tendons in Prestressed Concrete Containments | |
80 FR 52005 - Fisheries of the Northeastern United States; Atlantic Herring Fishery; Framework Adjustment 4 | |
80 FR 51961 - Fisheries of the Exclusive Economic Zone Off Alaska; Reallocation of Pollock in the Bering Sea and Aleutian Islands | |
80 FR 51973 - Initiation of Review of Management Plan and Regulations of the Monterey Bay National Marine Sanctuary; Intent To Conduct Scoping and Prepare Draft Environmental Impact Statement and Management Plan | |
80 FR 51965 - Airworthiness Directives; General Electric Company Turbofan Engines | |
80 FR 51935 - Airworthiness Directives; GE Aviation Czech s.r.o. Turboprop Engines | |
80 FR 52028 - Census Scientific Advisory Committee | |
80 FR 52027 - Sanders Resource Advisory Committee | |
80 FR 52026 - Sanders Resource Advisory Committee | |
80 FR 51957 - NASA Federal Acquisition Regulation Supplement: NASA Capitalization Threshold (NFS Case 2015-N004) | |
80 FR 51968 - Airworthiness Directives; Airbus Airplanes | |
80 FR 51966 - Airworthiness Directives; Pacific Aerospace Limited Airplanes | |
80 FR 51936 - Airspace Designations; Incorporation by Reference | |
80 FR 51970 - Proposed Establishment of Class E Airspace; Vancouver, WA | |
80 FR 52095 - Proposed Collection; Comment Request for Form 1099-CAP | |
80 FR 51972 - Proposed Establishment of Class E Airspace; International Falls, MN | |
80 FR 52068 - Self-Regulatory Organizations; NASDAQ OMX BX, Inc.; Notice of Filing of Proposed Rule Change To Adopt a Kill Switch | |
80 FR 52096 - Proposed Collection; Comment Request for Form 8569 | |
80 FR 51952 - Partial Approval and Disapproval of Air Quality Implementation Plans; Nebraska; Revision to the State Implementation Plan (SIP) Infrastructure Requirements for the 1997 and 2006 Fine Particulate Matter National Ambient Air Quality Standards and the Revocation of the PM10 | |
80 FR 52037 - Advisory Committee on Student Financial Assistance: Meeting | |
80 FR 52099 - Emission Guidelines and Compliance Times for Municipal Solid Waste Landfills | |
80 FR 52003 - Approval and Promulgation of Implementation Plans; New Mexico; Nonattainment New Source Review Permitting State Implementation Plan Revisions for the City of Albuquerque-Bernalillo County | |
80 FR 52162 - Standards of Performance for Municipal Solid Waste Landfills | |
80 FR 52002 - Approval and Promulgation of Air Quality Implementation Plans; State of Kansas; Infrastructure SIP Requirements for the 2008 Ozone National Ambient Air Quality Standard | |
80 FR 51955 - Approval and Promulgation of Implementation Plans; State of Kansas; Infrastructure SIP Requirements for the 2008 Ozone National Ambient Air Quality Standard | |
80 FR 51978 - Amendments to Domestic Production Activities Deduction Regulations; Allocation of W-2 Wages in a Short Taxable Year and in an Acquisition or Disposition | |
80 FR 51939 - Allocation of W-2 Wages in a Short Taxable Year and in an Acquisition or Disposition | |
80 FR 52015 - Fisheries Off West Coast States; Pacific Coast Groundfish Fishery Management Plan; Trawl Rationalization Program; Midwater Trawl Requirements |
Forest Service
Census Bureau
Foreign-Trade Zones Board
International Trade Administration
National Institute of Standards and Technology
National Oceanic and Atmospheric Administration
Energy Efficiency and Renewable Energy Office
Federal Energy Regulatory Commission
Centers for Disease Control and Prevention
Food and Drug Administration
National Institutes of Health
Coast Guard
U.S. Customs and Border Protection
Bureau of Safety and Environmental Enforcement
Fish and Wildlife Service
Land Management Bureau
National Park Service
National Endowment for the Arts
Federal Aviation Administration
Federal Transit Administration
Pipeline and Hazardous Materials Safety Administration
Alcohol and Tobacco Tax and Trade Bureau
Internal Revenue Service
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 LISTSERV electronic mailing list, go to http://listserv.access.thefederalregister.org and select Online mailing list archives, FEDREGTOC-L, Join or leave the list (or change settings); then follow the instructions.
Federal Aviation Administration (FAA), DOT.
Final rule.
We are adopting a new airworthiness directive (AD) for certain serial number (S/N) GE Aviation Czech s.r.o. M601E-11, M601E-11A, and M601F turboprop engines with certain part number (P/N) gas generator turbine (GGT) blades, installed. This AD requires removing from service any affected engine with certain GGT blades installed. This AD was prompted by the determination that certain GGT blades are susceptible to blade failure. We are issuing this AD to prevent GGT blade failure, which could lead to engine failure and loss of the airplane.
This AD becomes effective October 1, 2015.
See the
You may examine the AD docket on the Internet at
Robert Green, Aerospace Engineer, Engine Certification Office, FAA, Engine & Propeller Directorate, 12 New England Executive Park, Burlington, MA 01803; phone: 781-238-7754; fax: 781-238-7199; email:
We issued a notice of proposed rulemaking (NPRM) to amend 14 CFR part 39 by adding an AD that would apply to the specified products. The NPRM was published in the
It has been demonstrated that non-shot peened Gas Generator Turbine (GGT) blades are susceptible to blade separation in the shank area due to their reduced fatigue life.
This condition, if not corrected, could lead to an in-flight engine shutdown and, consequently, reduced control of the aeroplane.
We gave the public the opportunity to participate in developing this AD. We received no comments on the NPRM (80 FR 22136, April 21, 2015).
In our review of the NPRM, we found that we had included an S/N from the MCAI that was in error. We corrected the error by removing S/N 961001 from paragraph (c)(2) of this AD.
We reviewed the available data and determined that air safety and the public interest require adopting this AD with the changes described previously. We determined that these changes will not increase the economic burden on any operator or increase the scope of this AD.
We estimate that this AD affects one engine installed on an airplane of U.S. registry. We also estimate that it would take about 64 hours per engine to comply with this AD. The average labor rate is $85 per hour. Required parts cost about $28,765 per engine. Based on these figures, we estimate the cost of this AD on U.S. operators to be $34,205.
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.
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 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 to the extent that it justifies making a regulatory distinction, 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 becomes effective October 1, 2015.
None.
This AD applies to certain serial number (S/N) GE Aviation Czech s.r.o. M601E-11, M601E-11A, and M601F turboprop engine models, with gas generator turbine (GGT) blade, part number (P/N) M601-3372.6 or M601-3372.51, installed, as follows:
(1) Model M601E-11: S/Ns 862001, 863008, 894018, 034005, 034006, 034007, 034008, 041003, and 042002.
(2) Model M601E-11A: S/Ns 042003, 042004, 044001, and 044002.
(3) Model M601F: S/Ns 024001, 002001, 003001, 934001, 934002, 961001.
This AD was prompted by the determination that certain GGT blades are susceptible to blade failure. These blades are identified as blade P/Ns M601-3372.6 and M601-3372.51, and are installed on an engine S/N identified in paragraph (c) of this AD. We are issuing this AD to prevent GGT blade failure, which could lead to engine failure and loss of the airplane.
Comply with this AD within the compliance times specified, unless already done. After the effective date of this AD:
(1) Do not return to service any affected engine with GGT blade, P/N M601-3372.6 or M601-3372.51, installed, after 300 hours time in service or six months, whichever occurs first, after the effective date of this AD.
(2) If the affected engines are subsequently disassembled or overhauled, the non-shot peened GGT blades, P/N M601-3372.6 or M601-3372.51, are not eligible for installation in any other engine after removal.
The Manager, Engine Certification Office, FAA, may approve AMOCs for this AD. Use the procedures found in 14 CFR 39.19 to make your request. You may email your request to:
(1) For more information about this AD, contact Robert Green, Aerospace Engineer, Engine Certification Office, FAA, Engine & Propeller Directorate, 12 New England Executive Park, Burlington, MA 01803; phone: 781-238-7754; fax: 781-238-7199; email:
(2) Refer to MCAI European Aviation Safety Agency AD 2015-0015, dated January 30, 2015, for more information. You may examine the MCAI in the AD docket on the Internet at
None.
Federal Aviation Administration (FAA), DOT.
Final rule.
This action amends Title 14 Code of Federal Regulations (14 CFR) part 71 relating to airspace designations to reflect the approval by the Director of the Federal Register of the incorporation by reference of FAA Order 7400.9Z, Airspace Designations and Reporting Points. This action also explains the procedures the FAA will use to amend the listings of Class A, B, C, D, and E airspace areas; air traffic service routes; and reporting points incorporated by reference.
These regulations are effective September 15, 2015, through September 15, 2016. The incorporation by reference of FAA Order 7400.9Z is approved by the Director of the Federal Register as of September 15, 2015, through September 15, 2016.
FAA Order 7400.9Z, Airspace Designations and Reporting Points, and subsequent amendments can be viewed on line at
FAA Order 7400.9, Airspace Designations and Reporting Points, is published yearly and effective on September 15.
Sarah A. Combs, Airspace Policy and Regulations Group, Office of Airspace Services, Federal Aviation Administration, 800 Independence Avenue SW., Washington, DC 20591; telephone: (202) 267-8783.
FAA Order 7400.9Y, Airspace Designations and Reporting Points, effective September 15, 2014, listed Class A, B, C, D and E airspace areas; air traffic service routes; and reporting points. Due to the length of these descriptions, the FAA requested approval from the Office of the Federal Register to incorporate the material by reference in the Federal Aviation Regulations section 71.1, effective September 15, 2014, through September 15, 2015. During the incorporation by reference period, the FAA processed all proposed changes of the airspace listings in FAA Order 7400.9Y in full text as proposed rule documents in the
This document incorporates by reference FAA Order 7400.9Z, airspace Designations and Reporting Points, dated August 6, 2015, and effective September 15, 2015, in section 71.1. FAA Order 7400.9Z is publicly available as listed in the
This action amends Title 14 Code of Federal Regulations (14 CFR) part 71 to reflect the approval by the Director of the Federal Register of the incorporation by reference of FAA Order 7400.9Z, effective September 15, 2015, through September 15, 2016. During the incorporation by reference period, the FAA will continue to process all proposed changes of the airspace listings in FAA Order 7400.9Z in full text as proposed rule documents in the
The FAA has determined that this action: (1) Is not a “significant regulatory action” under Executive Order 12866; (2) is not a “significant rule” under DOT Regulatory Policies and Procedures (44 FR 11034; February 26, 1979); and (3) does not warrant preparation of a regulatory evaluation as the anticipated impact is so minimal. This action neither places any new restrictions or requirements on the public, nor changes the dimensions or operation requirements of the airspace listings incorporated by reference in part 71.
Airspace, Incorporation by reference, Navigation (air).
In consideration of the foregoing, the Federal Aviation Administration amends 14 CFR part 71 as follows:
49 U.S.C. 106(f), 106(g); 40103, 40113, 40120; E.O. 10854, 24 FR 9565, 3 CFR, 1959-1963 Comp., p. 389.
A listing for Class A, B, C, D, and E airspace areas; air traffic service routes; and reporting points can be found in FAA Order 7400.9Z, Airspace Designations and Reporting Points, dated August 6, 2015. This incorporation by reference was approved by the Director of the Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. The approval to incorporate by reference FAA Order 7400.9Z is effective September 15, 2015, through September 15, 2016. During the incorporation by reference period, proposed changes to the listings of Class A, B, C, D, and E airspace areas; air traffic service routes; and reporting points will be published in full text as proposed rule documents in the
Food and Drug Administration, HHS.
Final order.
The Food and Drug Administration (FDA) is classifying
This order is effective September 28, 2015. The classification was applicable April 30, 2012.
Noel Gerald, Center for Devices and Radiological Health, Food and Drug Administration, 10903 New Hampshire Ave., Bldg. 66, Rm. 5566, Silver Spring, MD 20993-0002, 301-796-4695.
In accordance with section 513(f)(1) of the Federal Food, Drug, and Cosmetic Act (the FD&C Act) (21 U.S.C. 360c(f)(1)), devices that were not in commercial distribution before May 28, 1976 (the date of enactment of the Medical Device Amendments of 1976), generally referred to as postamendments devices, are classified automatically by statute into class III without any FDA rulemaking process. These devices remain in class III and require premarket approval, unless and until the device is classified or reclassified into class I or II, or FDA issues an order finding the device to be substantially equivalent, in accordance with section 513(i) of the FD&C Act, to a predicate device that does not require premarket approval. The Agency determines whether new devices are substantially equivalent to predicate devices by means of premarket notification procedures in section 510(k) of the FD&C Act (21 U.S.C. 360(k)) and part 807 (21 CFR part 807) of the regulations.
Section 513(f)(2) of the FD&C Act, as amended by section 607 of the Food and Drug Administration Safety and Innovation Act (Pub. L. 112-144), provides two procedures by which a person may request FDA to classify a device under the criteria set forth in section 513(a)(1). Under the first procedure, the person submits a premarket notification under section 510(k) of the FD&C Act for a device that has not previously been classified and, within 30 days of receiving an order classifying the device into class III under section 513(f)(1) of the FD&C Act, the person requests a classification under section 513(f)(2). Under the second procedure, rather than first submitting a premarket notification under section 510(k) of the FD&C Act and then a request for classification under the first procedure, the person determines that there is no legally marketed device upon which to base a determination of substantial equivalence and requests a classification under section 513(f)(2) of the FD&C Act. If the person submits a request to classify the device under this second procedure, FDA may decline to undertake the classification request if FDA identifies a legally marketed device that could provide a reasonable basis for review of substantial equivalence with the device or if FDA determines that the device submitted is not of “low-moderate risk” or that general controls would be inadequate to control the risks and special controls to mitigate the risks cannot be developed.
In response to a request to classify a device under either procedure provided by section 513(f)(2) of the FD&C Act, FDA will classify the device by written order within 120 days. This classification will be the initial classification of the device.
In accordance with section 513(f)(1) of the FD&C Act, FDA issued an order on February 3, 2012, automatically classifying the Portrait Toxigenic
In accordance with section 513(f)(2) of the FD&C Act, FDA reviewed the request for de novo classification in order to classify the device under the criteria for classification set forth in section 513(a)(1). FDA classifies devices into class II if general controls by themselves are insufficient to provide reasonable assurance of safety and effectiveness, but there is sufficient information to establish special controls to provide reasonable assurance of the safety and effectiveness of the device for its intended use. After review of the information submitted in the request, FDA determined that the device can be classified into class II with the establishment of special controls. FDA believes these special controls will provide reasonable assurance of the safety and effectiveness of the device.
Therefore, on April 30, 2012, FDA issued an order to the requestor classifying the device into class II. FDA is codifying the classification of the device by adding § 866.3130.
Following the effective date of this final classification administrative order, any firm submitting a premarket notification (510(k)) for a
The device is assigned the generic name
FDA has identified the following risks to health associated with this type of device and the measures required to mitigate these risks:
FDA believes that the measures set forth in the special controls guideline entitled “Class II Special Controls Guideline: Toxin Gene Amplification Assays for the Detection of
A
The Agency has determined under 21 CFR 25.34(b) that this action is of type that does not individually or cumulatively have a significant effect on the human environment. Therefore, neither an environmental assessment nor an environmental impact statement is required.
This final administrative order establishes special controls that refer to previously approved collections of information found in other FDA regulations. These collections of information are subject to review by the Office of Management and Budget (OMB) under the Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3520). The collections of information in part 807, subpart E, regarding premarket notification submissions have been approved under OMB control number 0910-0120; the collections of information in 21 CFR part 820 have been approved under OMB control number 0910-0073; and the collections of information in 21 CFR parts 801 and 809 have been approved under OMB control number 0910-0485.
Biologics, Laboratories, Medical devices.
Therefore, under the Federal Food, Drug, and Cosmetic Act and under authority delegated to the Commissioner of Food and Drugs, 21 CFR part 866 is amended as follows:
21 U.S.C. 351, 360, 360c, 360e, 360j, 371.
(a)
(b)
Internal Revenue Service (IRS), Treasury.
Final and temporary regulations.
This document contains final and temporary regulations relating to the allocation of W-2 wages for purposes of the W-2 wage limitation on the amount of a taxpayer's deduction related to domestic production activities. Specifically, the temporary regulations provide guidance on: the allocation of W-2 wages paid by two or more taxpayers that are employers of the same employees during a calendar year; and the determination of W-2 wages if the taxpayer has a short taxable year. The text of the temporary regulations
James A. Holmes 202-317-4137 (not a toll free call).
This document contains amendments to the Income Tax Regulations (26 CFR part 1) under section 199(b) of the Internal Revenue Code (Code). Section 199(b) was enacted by the American Jobs Creation Act of 2004 (Pub. L. 108-357, 118 Stat. 1418 (2004)). Subsequent amendments to section 199(b) were made by the Gulf Opportunity Zone Act of 2005 (Pub. L. 109-135, 119 Stat. 25 (2005)), the Tax Increase Prevention and Reconciliation Act of 2005 (Pub. L. 109-222, 120 Stat. 345 (2005)), the Tax Extenders and Alternative Minimum Tax Relief Act of 2008 (Pub. L. 110-343, 122 Stat 3765 (2008)), and the Tax Increase Prevention Act of 2014 (Pub. L. 113-295, 128 Stat. 4010 (2014)).
Under section 199(b)(1), the amount of the deduction allowable under section 199(a) for any taxable year shall not exceed 50 percent of the W-2 wages of the taxpayer for the taxable year. Section 199(b)(2)(A) generally defines
Section 1.199-2(c) currently provides that if a taxpayer (a successor) acquires a trade or business, the major portion of a trade or business, or the major portion of a separate unit of a trade or business from another taxpayer (a predecessor), then, for purposes of computing the respective section 199 deduction of the successor and of the predecessor, the W-2 wages paid for that calendar year shall be allocated between the successor and the predecessor based on whether the wages are for employment by the successor or for employment by the predecessor. Thus, the W-2 wages are allocated based on whether the wages are for employment for a period during which the employee was employed by the predecessor or for employment for a period during which the employee was employed by the successor. The W-2 wage allocation under the current regulations is made regardless of which permissible method is used by a predecessor or a successor for reporting wages on Form W-2, as provided in Rev. Proc. 2004-53 (2004-2 CB 320) (see § 601.601(d)(2) of this chapter). Section 1.199-2(e)(1) provides that under section 199(b)(2), the term
Rev. Proc. 2006-47 (2006-2 CB 869) (see § 601.601(d)(2)) is the currently effective guidance providing methods of calculating W-2 wages and related rules for purposes of section 199(b). Section 6.02(A) of Rev. Proc. 2006-47 provides that the amount of W-2 wages for a taxpayer with a short taxable year includes only those wages subject to Federal income tax withholding that are reported on Form W-2, “Wage and Tax Statement,” for the calendar year ending with or within that short taxable year.
In certain situations, a short taxable year may not include a calendar year ending within such short taxable year. Section 1.199-2(c) of the current regulations does not address these situations and does not reflect the amendment made by the Tax Increase Prevention Act of 2014. In order to provide guidance on the application of section 199(b)(3) to a short taxable year that does not include a calendar year ending within the short taxable year, the IRS and the Treasury Department are revising the regulations to address these situations. To provide immediate effect, the IRS and the Treasury Department are issuing these regulations as temporary regulations. These temporary regulations apply solely for purposes of section 199.
The final regulations issued in connection with these temporary regulations remove the current language of § 1.199-2(c) and replace it with a cross reference to these temporary regulations. In the place of the current language, these temporary regulations provide rules for calculating W-2 wages for purposes of the W-2 wage limitation in the case of an acquisition or disposition of a trade or business, the major portion of a trade or business, the major portion of a separate unit of a trade or business during the taxable year, or a short taxable year. Specifically, these temporary regulations provide a rule for acquisitions and dispositions if one or more taxpayers may be considered the employer of the employees of the acquired or disposed of trade or business during that calendar year. In that case, the temporary regulations provide that the W-2 wages paid during the calendar year to employees of the acquired or disposed of trade or business are allocated between each taxpayer based on the period during which the employees of the acquired or disposed of trade or business were employed by the taxpayer.
These temporary regulations also provide a rule to apply in the case of a short taxable year in which there is no calendar year ending within such short taxable year (short-taxable-year rule). Wages paid by a taxpayer during the short taxable year to employees for employment by such taxpayer are treated as W-2 wages for such short taxable year for purposes of section 199(b)(1).
These temporary regulations also describe types of transactions that are considered either an acquisition or disposition for purposes of section 199(b)(3). Specifically, these temporary regulations provide that an acquisition or disposition includes an incorporation, a formation, a liquidation, a reorganization, or a purchase or sale of assets.
These regulations also contain cross references to § 1.199-2(a), (b), (d), and (e). The IRS and the Treasury Department observe that these rules continue to apply to taxpayers that use these temporary regulations. For example, the non-duplication rule of § 1.199-2(d) applies such that a taxpayer that includes wages as W-2 wages based on these temporary regulations, including by filing an amended return for a short taxable year, may not treat those wages as W-2 wages for any other taxable year. Also, wages qualifying as W-2 wages of one taxpayer
The temporary regulations are applicable for taxable years beginning on or after August 27, 2015 and expire on August 24, 2018. A taxpayer may apply § 1.199-2T(c) to taxable years for which the limitations for assessment of tax has not expired beginning before August 27, 2015.
Certain IRS regulations, including this one, are exempt from the requirements of Executive Order 12866 of, as supplemented and reaffirmed by Executive Order 13563. Therefore, a regulatory assessment is not required. It also has been determined that section 533(b) of the Administrative Procedure Act (5 U.S.C. chapter 5) does not apply to these regulations. For the applicability of the Regulatory Flexibility Act (5 U.S.C. chapter 6) refer to the Special Analyses section of the preamble to the cross-reference notice of proposed rulemaking published in the Proposed Rules section in this issue of the
The principal author of these regulations is James A. Holmes, Office of Associate Chief Counsel (Passthroughs and Special Industries). However, other personnel from the IRS and Treasury Department participated in their development.
Income taxes, Reporting and recordkeeping requirements.
Accordingly, 26 CFR part 1 is amended as follows:
26 U.S.C. 7805 * * *
Section 1.199-2T also issued under 26 U.S.C. 199(b)(3).
(c) Acquisitions, dispositions, and short taxable years.
(1) Allocation of wages between more than one taxpayer.
(2) Short taxable years.
(3) Operating rules.
(i) Acquisition or disposition.
(ii) Trade or business.
(i) * * *
(10) Acquisitions, dispositions, and short taxable years.
(c) [Reserved]. For further guidance see § 1.199-2T(c).
(a) through (b) [Reserved]. For further guidance, see § 1.199-2(a) through (b).
(c)
(2)
(3)
(ii)
(iii)
(d) through (e) [Reserved]. For further guidance, see § 1.199-2(d) through (e).
(i) * * *
(10)
(a) through (h) [Reserved]. For further guidance, see § 1.199-8(a) through (h).
(i)
(10)
(11)
Coast Guard, DHS.
Notice of deviation from drawbridge regulations.
The Coast Guard has issued a temporary deviation from the operating schedule that governs the US 70 (Grayden Paul) Bridge across Gallants Channel, mile 0.1, at Beaufort, NC. This temporary deviation allows the draw bridge to remain in the closed to navigation position to accommodate The Neuse Riverkeeper Foundation Triathlon participants to safely complete their race without interruptions from bridge openings.
This deviation is effective from 10 a.m. to 1:30 p.m. on September 12, 2015.
The docket for this deviation, [USCG-2015-0742] 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 for the Neuse Riverkeeper Foundation Triathlon, with approval from the North Carolina Department of Transportation, owner of the drawbridge, has requested a temporary deviation from the operating schedule to accommodate the Neuse Riverkeeper Foundation Triathlon.
The US 70 (Grayden Paul) Bridge operating regulations are set out in 33 CFR 117.823. The US 70 (Grayden Paul) Bridge across Gallants Channel, mile 0.1, a double-leaf bascule bridge, in Beaufort, NC has a vertical clearance in the closed position of 13 feet above mean high water.
Under this temporary deviation, the drawbridge will be allowed to remain in the closed-to-navigation position from 10 a.m. to 1:30 p.m. on Saturday, September 12, 2015 while race participants are competing in the Neuse Riverkeeper Foundation Triathlon.
The majority of the vessels that transit the bridge this time of the year are recreational boats. Vessels able to pass under the bridge in the closed position may do so at anytime and are advised to proceed with caution. The bridge will be able to open for emergencies and there is no alternate route for vessels to pass. The Coast Guard will also inform the users of the waterways through our Local and Broadcast Notices to Mariners of the change in operating schedule for the bridge so that vessels can arrange their transits to minimize any impact 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 designated time period. 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 Sacramento County highway bridge across Sacramento River, mile 46.0, at Freeport, CA. The deviation is necessary to allow the bridge owner to replace bridge counterweight bolts. This deviation allows single leaf operation of the double bascule highway bridge during the deviation period.
This deviation is effective without actual notice from August 27, 2015 to 6 a.m. on September 11, 2015. For the purposes of enforcement, actual notice will be used from 8 p.m. on August 17, 2015, until August 27, 2015.
The docket for this deviation, [USCG-2015-0792], is available at
If you have questions on this temporary deviation, call or email David H. Sulouff, Chief, Bridge Section, Eleventh Coast Guard District; telephone 510-437-3516, email
The County of Sacramento has requested a temporary change to the operation of the Sacramento County highway bridge, a double bascule drawbridge, mile 46.0, over Sacramento River, at Freeport, CA. The drawbridge navigation span provides 29 feet vertical clearance above Mean High Water in the closed-to-navigation position. In accordance with 33 CFR 117.189(b), the draw opens on signal from May 1 through September 30 from 9 a.m. to 5 p.m. At all other times, the draw shall open on signal if at least four hours notice is give to the drawtender at the Rio Vista Bridge across the Sacramento River, mile 12.8. Navigation on the waterway is recreational and commercial.
Single leaf operation of the Sacramento County highway drawbridge will occur from 8 p.m. on August 17, 2015 to 6 a.m. on September 11, 2015, to allow the bridge owner to replace corroded counterweight bolts. This temporary deviation has been coordinated with the waterway users. No objections to the proposed temporary deviation were raised.
Vessels able to pass through the bridge in the closed position may do so at any time. The bridge will be able to open for emergencies with one leaf in full operational status. There is no alternate route for vessels to pass through the bridge in the closed position. The Coast Guard will also inform waterway users through our Local and Broadcast Notices to Mariners
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.
Final rule.
The Coast Guard is establishing regulations for annual, combined marine events that require the establishment of a temporary safety zone within the Captain of the Port Zone Buffalo on the Cuyahoga River, Cleveland, OH. This safety zone regulation is necessary to protect the surrounding public, spectators, participants, and vessels from the hazards associated with the rowing regatta in the narrow waterway of the Cuyahoga River. This rule is intended to restrict vessels annually from a portion of the Cuyahoga River for up to 9 hours during the combined Dragon Boat Festival and the Head of the Cuyahoga Regatta.
This rule is effective September 28, 2015.
Documents mentioned in this preamble are part of docket [USCG-2014-0082]. 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 LT Stephanie Pitts, Chief of Waterways Management, U.S. Coast Guard Marine Safety Unit Cleveland; telephone 216-937-0128, email
The Head of the Cuyahoga (HOTC) rowing regatta has occurred annually for over a decade and the Dragon Boat Festival for the last 8 years. In response to past years' events, the Coast Guard established a temporary safety zone to protect the boating public. For example, in 2013, the Captain of the Port Buffalo initiated a rulemaking (78 FR 42736, July 17, 2013) to ensure the safety of spectators and vessels during the rowing event. The safety zone in this final rule is identical in size, location, and effect as that established by the 2013 rulemaking.
As mentioned in the “Regulatory History and Information” section, the HOTC is an annual rowing regatta that has taken place for over a decade. The HOTC takes place on the Cuyahoga River along a 4800 meter course and attracts numerous rowing clubs and programs from across the U.S. Typically, the event occurs on the third Saturday of September between the hours of 7 a.m. and 4 p.m. In 2014, the HOTC occurred between 6 a.m. and 4 p.m. on September 20th.
In conjunction with the HOTC, the Seventh Annual Cleveland Dragon Boat Festival will take place from Superior/Nautica Bend to just north of the Detroit Superior Viaduct Bridge. The Dragon Boat festival will feature three head-to-head races being held over the course of the day.
The Captain of the Port Buffalo has determined that the HOTC and the Cleveland Dragon Boat Festival rowing events present significant hazards to public spectators and participants.
We received one comment on the NPRM (79 FR 24656). This comment requested the time of enforcement be changed from 10 hours to 9 hours and to begin at 7 a.m. in lieu of the proposed 6 a.m. and still end at 4 p.m. as originally proposed. This change was requested for the better facilitation of trade on the Cuyahoga River. Of note, the commenter, Great Lakes Carriers Association noted that they completed a memorandum of agreement with the Cuyahoga River rowing foundation to address this very issue and to formalize the agreement between them to better allow for diverse use of the river without hampering trade and vital to the local economy. The Coast Guard, upon reviewing the comment considers the change to the proposal to be in the best interest of this rule and has amended the final rule to be effective for 9 hours, beginning at 7 a.m. and ending at 4 p.m. as requested.
The enforcement date and times for the safety zone that is listed in 33 CFR 165.T09-0082 is to occur on the 3rd Saturday of September of each year and to begin 7 a.m. and end at 4 p.m. For any given year, the Captain of the Port Sector Buffalo will provide notice to the public by publishing a Notice of Enforcement in the
Entry into, transiting, or anchoring within the safety zones identified in § 165.T09-0082 will be prohibited unless authorized by the Captain of the Port Buffalo or his on-scene representative. The Captain of the Port or his on-scene representative may be contacted via VHF Channel 16.
We developed this rule after considering numerous statutes and executive orders related to rulemaking. Below we summarize our analyses based on these statutes or executive orders.
This rule is not a significant regulatory action under section 3(f) of Executive Order 12866, Regulatory Planning and Review, as supplemented by Executive Order 13563, Improving Regulation and Regulatory Review, and does not require an assessment of potential costs and benefits under section 6(a)(3) of Executive Order 12866 or under section 1 of Executive Order 13563. The Office of Management and Budget has not reviewed it under those Orders.
Under the Regulatory Flexibility Act (5 U.S.C. 601-612), we have considered the impact of this rule on small entities. The Coast Guard received no comments from the Small Business Administration on this rule. The Coast Guard certifies under 5 U.S.C. 605(b) that this rule will not have a significant economic impact on a substantial number of small entities.
This rule would affect the following entities, some of which might be small entities: The owners and operators of vessels intending to transit or anchor in the safety zone while the zone is being enforced. The safety zone will not have a significant economic impact on a substantial number of small entities for the following reasons: Each safety zone in this rule will be in enforced for no more than 9 hours in any 24 hour period and enforced only once per year and will be in areas with low commercial vessel traffic. Furthermore, this safety zone has been designed to mitigate the delay to traffic by shortening the enforcement period. In the event that a safety zone affects shipping, commercial vessels may request permission from the Captain of the Port Buffalo or his or her designated representative to transit the safety zone or remain in the safety zone during the event.
If you think that your business, organization, or governmental jurisdiction qualifies as a small entity and that this rule would have a significant economic impact on it, please contact the person listed in the
Under section 213(a) of the Small Business Regulatory Enforcement Fairness Act of 1996 (Pub. L. 104-121), we want to assist small entities in understanding this 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 determined that this rule does not have implications for federalism.
The Coast Guard respects the First Amendment rights of protesters. Protesters are asked to 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 would not result in such an expenditure, we do discuss the effects of this rule elsewhere in this preamble.
This rule would not cause a taking of private property or otherwise have taking implications under Executive Order 12630, Governmental Actions and Interference with Constitutionally Protected Property Rights.
This rule meets applicable standards in sections 3(a) and 3(b)(2) of Executive Order 12988, Civil Justice Reform, to minimize litigation, eliminate ambiguity, and reduce burden.
We have analyzed this rule under Executive Order 13045, Protection of Children from Environmental Health Risks and Safety Risks. This rule is not an economically significant rule and would not create an environmental risk to health or risk to safety that might disproportionately affect children.
This rule does not have tribal implications under Executive Order 13175, Consultation and Coordination with Indian Tribal Governments, because it would 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.
This rule is not a “significant energy action” under Executive Order 13211, Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use.
This rule does not use technical standards. Therefore, we did not consider the use of voluntary consensus standards.
We have analyzed this rule under Department of Homeland Security Management Directive 023-01 and Commandant Instruction M16475.lD, which guide the Coast Guard in complying with the National Environmental Policy Act of 1969 (NEPA) (42 U.S.C. 4321-4370f), and have made a preliminary determination that this action is one of a category of actions that do not individually or cumulatively have a significant effect on the human environment. This rule is categorically excluded, under figure 2-1, paragraph (34)(g), of the Commandant Instruction because it involves the establishment of a safety zone.
An environmental analysis checklist and a categorical exclusion determination are available in the docket where indicated under
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 parts 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)
(1) “On-scene Representative” means any Coast Guard commissioned, warrant, or petty officer designated by the Captain of the Port Buffalo to monitor a safety zone, permit entry into the zone, give legally enforceable orders to persons or vessels within the zones, and take other actions authorized by the Captain of the Port.
(2) “Public vessel” means vessels owned, chartered, or operated by the United States, or by a State or political subdivision thereof.
(d)
(2) The safety zone identified in paragraph (a) of this section is closed to all vessel traffic, except as may be permitted by the Captain of the Port Buffalo or his designated on-scene representative.
(3) Vessel operators desiring to enter or operate within the safety zone must contact the Captain of the Port Buffalo or his on-scene representative to obtain permission to do so. The Captain of the Port Buffalo or his on-scene representative may be contacted via VHF Channel 16. Vessel operators given permission to enter or operate in the safety zone must comply with all directions given to them by the Captain of the Port Buffalo, or his on-scene representative.
(4) Additionally, all vessels over 65 feet intending to transit, moor or conduct operations to include loading or discharging of cargo or passengers in the Cuyahoga River while the safety zone is being enforced should request permission from the COTP or his/her designated representative at least 12 hours before the zone is established.
(e)
(f)
National Park Service, Interior.
Final rule.
The rule authorizes and allows for the management of bicycle use on certain new trails within Cuyahoga Valley National Park. The National Park Service general regulation pertaining to bicycles requires promulgation of a special regulation to authorize bicycle use on new trails constructed outside of developed areas.
The rule is effective September 28, 2015.
Lisa Petit, Chief of Resource Management, Cuyahoga Valley National Park, (440) 546-5970.
On December 27, 1974, President Gerald Ford signed Pub. L. 93-555 creating Cuyahoga Valley National Recreation Area for the purpose of “preserving and protecting for public use and enjoyment, the historic, scenic, natural, and recreational values of the Cuyahoga River and the adjacent lands of the Cuyahoga Valley and for the purpose of providing for the maintenance of needed recreational open space necessary to the urban environment.” In 2000, Congress redesignated Cuyahoga Valley National Recreation Area as Cuyahoga Valley National Park (CUVA or Park) with the passage of the Department of the Interior and Related Agencies Appropriations Act (Pub. L. 106-291).
CUVA is an important national resource within a predominantly metropolitan region, where the Park is visited by approximately 2,500,000 people annually. Located in Cuyahoga and Summit Counties, Ohio, and situated between the cities of Cleveland and Akron, CUVA includes approximately 33,000 acres of land, with 19,000 acres under the administration of the National Park Service (NPS). The Park contains significant resources, including the Cuyahoga River Valley and its associated ecological functions, rich cultural resources and landscapes, and a variety of recreational and outdoor use opportunities.
In the 1930's the Cuyahoga Valley provided a respite for urban dwellers from Cleveland and Akron. During this time period, private estates in the Cuyahoga Valley had established trails and carriage roads for their private recreational enjoyment, including places like the Old Carriage trail area and the Wetmore trails. Over the years, these lands and other park lands were incorporated into the Cleveland Metroparks and Summit Metro Parks that are now part of what is designated as CUVA. Two significant trail corridors accelerated the recreational connections to the Valley: The conversion of an abandoned railroad bed to the Bike and Hike Trail in 1970 and the construction of the Towpath Trail in the late 1980's and early 1990's. Many of the trails from the earliest days of Cuyahoga Valley as a recreation destination remain today for visitors to enjoy and share the
The Park's General Management Plan/Environmental Impact Statement (GMP) confirms the purpose, significance, and special mandates of the Park. According to the Park's GMP, one of the significant purposes of CUVA is to “[preserve] a landscape reminiscent of simpler times, a place where recreation can be a gradual process of perceiving and appreciating the roots of our contemporary existence.” The GMP also provides direction for park management during land acquisition and provides a framework for NPS managers to use when making decisions about how to conserve the Park's resources and manage visitor uses in the Park. Resource preservation for compatible recreational use is the overall concept for management and development of the Park.
Regional recreational trail networks have blossomed across Northeastern Ohio, increasing demands for additional trail connections, new trail uses, and expanded recreational opportunities. Today, the Park contains approximately 175 miles of trails, approximately 97 miles of which are managed by the NPS. The NPS trail system consists of three long-distance trails—the Towpath Trail, Buckeye Trail and Valley Bridle Trail—and eleven smaller localized trail systems with separate access points. The park currently has one limited community connector through the Old Carriage Trail connector trail in the northern portion of the park and has some portions of the primary roadways improved for bike use. Metropark partners provide five additional trail systems within their units inside CUVA, and another trail, the Buckeye Trail, is managed by the Buckeye Trail Association. Currently, the Park provides access to all its trails through 25 trailheads and from the four primary Visitor Contact Centers.
These trails provide for various uses, including 34 miles for hiking and trail running only, 22 miles for multipurpose biking and hiking, 17 miles for cross-country skiing, and 35 miles for equestrian riding. Nonetheless, requests for new trail uses to meet the needs of growing user groups have become more frequent in recent years. Technologies exist today (such as personal mobility devices) that provide new means to enjoy trails. Walk‐in camping is a desired amenity that recently was approved for the first time in the park. Trail running is increasing in popularity, and biking has grown into a major recreational activity within the Cuyahoga Valley.
In 1985, the Park's first Trail Management Plan was developed as the primary document to initiate many trails in the Park. The 1985 Trail Plan identified 105 miles of existing trails and proposed and evaluated 115 miles of new trail. An additional 46 miles of trails were identified for future consideration but were not evaluated in the 1985 Trail Plan. In 2013, CUVA completed a Comprehensive Trails Management Plan/Environmental Impact Statement (TMP/EIS) to guide the expansion, restoration, management, operations, and use of the trail system and its associated amenities over the next 15 years, while keeping with the purpose, mission, and significance of the Park. Some trails proposed in the 1985 Trail Plan but not yet implemented were considered as part of the TMP/EIS.
The goals of the TMP/EIS were to develop a trail network that:
• Provides experiences for a variety of trail users;
• shares the historic, scenic, natural and recreational significance of the Park;
• minimizes impacts to the park's historic, scenic, natural and recreational resources;
• can be sustained; and
• engages cooperative partnerships that contribute to the success of the Park's trail network.
The Park conducted internal scoping with Park staff, regional park district partners, and the Conservancy for Cuyahoga Valley National Park and external scoping, including the mailing and distribution of four separate newsletters, nine public meetings, and a 60-day public comment period. As a result of this process, eight alternatives, including a “No Action Alternative,” for the Park's Trail Management Plan were developed.
The Record of Decision (ROD), for the TMP/EIS, signed by the NPS Midwest Regional Director on August 8, 2013, identified the Preferred Alternative 5 as the Selected Alternative for implementation. Under this Alternative, approximately 14.5 miles of new bicycle trails could be constructed in undeveloped regions of the park and authorized by special regulations for bicycle use. The Alternative also considers approximately eight additional miles of existing trail or roadways that could be authorized for bicycle use in the future. The construction and authorization of these trails for bicycle use will be conditional on funding and subject to the development of other facilities or activities (including evaluation of resource impacts) conducted prior to implementation.
Due to the age and conceptual nature of the 1977 GMP, a 2013 Foundation Document was developed for the Park that identifies active recreation and implementation of the TMP/EIS as an objective to meets its goals. The TMP/EIS and ROD may be viewed online at
Many of the proposed bicycle trails have not yet been built and will not be immediately open for use. An Implementation Strategy is under development to prioritize trail projects and assemble the additional planning, funding, staffing, project management, and monitoring that will be needed to accomplish them successfully. The Trails Forever Program, administered by the Park in partnership with the Conservancy for Cuyahoga Valley National Park, will be the overarching program under which this implementation strategy will be realized.
Volunteers for trail work at the Park will continue to be a vital component of trail stewardship in the Park. Management and coordination of volunteers will continue through the joint Volunteer Program office of the Park and the Conservancy for Cuyahoga Valley National Park. The use of Park staff and the existing volunteer trail groups to monitor and mitigate the environmental impacts of bicycle use on these trails will ensure that the trails are maintained in good condition and that any issues of concern are immediately brought to the attention of Park management. In addition, the Park will continue to update its Sign Plan and upgrade park and trail signs accordingly. As trail signs are updated, trail accessibility information for each trail will be made available to the public.
On October 14, 2014 the NPS published a proposed rule that would authorize and allow for management of bicycle use on certain new trails within CUVA, (79 FR 61587). The proposed rule was available for a 60-day public comment period, from October 14, 2014 through December 15, 2014. Comments were accepted through the mail, by hand delivery, and through the Federal eRulemaking Portal:
The NPS received 300 public comments during the comment period. Responses to the comments mostly referred to the
The 276 supporting comments expressed eight central themes:
The authorization of off-road bicycle use in CUVA will expand the utilization of the park by new users, including youth and families, by providing new and exciting opportunities to participate in outdoor recreation activities. Providing younger members of society with off-road bicycling opportunities encourages them to develop a sense of pride and ownership in the trails they ride and maintain, creating the next generation of stewards. It is well substantiated that there are many individuals that enjoy this activity in other parks and on other public lands outside of the region with only a few areas available within the region. Recent years have seen new trails within Cleveland Metroparks and Summit Metro Parks and the activity continues to grow in popularity as evidenced by an increase in bike sales.
Allowing off-road bicycle use is important for public health because it contributes to healthy, active lifestyles and getting people out into nature. Bike riding is well established as a significant form of exercise that contributes to personal health and well-being. By providing for greater use of bicycles on trails more people can benefit from this form of exercise as well enjoying time in the out of doors
Allowing off-road bicycle use is an important draw for tourism and a catalyst for economic development in and around CUVA and the northeast Ohio region. CUVA serves increasingly as a destination for out of town visitors crossing the country and visiting national parks. With the addition of off-road single track bike trails, the park and region will be even more inviting as a destination for extended-stay excursions. Bike trails are well known to be a quality of life indicator and an attraction for young professionals and others looking to relocate for jobs and family.
Off-road bicycle use is environmentally appropriate and can contribute to protection of natural and cultural resources. This has been demonstrated both outside of our region and within our area, where many individuals who are avid off-road bicyclists frequently volunteer for trail maintenance and stewardship activities. The bicycling community provides extensive education to encourage volunteerism and environmental stewardship. This education includes trail etiquette to facilitate coexistence among user groups, and to model appropriate use of the trails systems for improved safety. Local park districts within the surrounding communities have developed a volunteer network of trail stewards that maintain and patrol trails and report when conditions are not favorable for riding and/or when closing a trail is needed to prevent damage.
The NPS is a trusted source for protection of natural resources and included a robust planning process and Sustainable Trail Design Guidelines in the preparation of the TMP/EIS. These activities reinforce the communities' knowledge and appreciation for appropriate planning processes, and provide leadership in the execution of sustainable trail building practices that will benefit other public land stewards in the region. Safety is a primary design criterion for trail improvements within the park and is central to considerations for operational and utilization decisions.
Allowing off-road bicycle use will make remote parts of CUVA more accessible to some visitors who want to experience the full breadth of resources in the park. Additionally, there will be opportunities for additional linkages and looped systems within the existing trail network.
Bicycle trails in CUVA have been the center point for partnerships and community development, such as the volunteer efforts of the Boy Scouts to build the Arrowhead Trail. If permanent access for bicycle use is allowed, these relationships will continue to flourish, building a sense of stewardship among trail users and park staff.
The construction of single track off-road bicycle trails will exemplify sustainable construction practices and provide an educational opportunity to the public and volunteers participating in construction and maintenance. This exposure will enable users to better understand the sensitivity of natural resources and how proper design practices are necessary for protection and conservation. Volunteers can become engaged in the on-going maintenance and consequently learn firsthand the proper construction and maintenance techniques to protect natural resources. This has been demonstrated both outside of our region and within our area where many individuals who are avid off-road bicyclists frequently volunteer for trail maintenance and stewardship activities.
Some commenters supported the new bicycle rule but also had questions, asked for clarifications, or proposed ideas for which the NPS has prepared responses. These comments are paraphrased and answered below:
1.
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3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
One neutral commenter proposed ideas for which the NPS has prepared a response. The comment is paraphrased and answered below:
The 24 comments submitted in opposition to off-road bicycle trails were focused on five primary areas of concern: Impacts on natural resources; User conflicts-safety; User conflicts-visitor experience; NPS operational burden; and Inconsistency with NPS mission.
The most common concern expressed by commenters in opposition to the proposed rule was that off-road bicycles cause serious impacts to natural resources, including wildlife habitat, plants, soils, and water quality.
(1) Trail building destroys wildlife habitat! It not only destroys the habitat under and next to the trail, but it renders a wide swathe of habitat on either side of the trail useless to the wildlife, due to the presence of people.
(2) Each time a pathway is created, that new opening allows invasive species into that area, both plant and animal.
(3) This is not a good idea. The trails already suffer erosion from heavy use and allowing mountains bikes will only worsen the problem.
(4) Constructing new trails removes vegetation, which fragments habitats, risks destroying important or rare species, and can contribute to high soil erosion, which leads to water contamination.
Most comments in opposition to the proposed rule expressed concern for safety of hikers sharing trails with off-road bicycles, primarily due to concerns about speed and inconsiderate/intimidating behavior of bikers, as well as a perception that bikers have little regard for authority or regulations.
(1) If you have ever tried to hike around large, fast-moving pieces of machinery such as bicycles, you know that it is scary and no fun!
(2) I avoid areas used by mountain bikers because, generally speaking, they are rude by not signaling when approaching from behind and scare the “heck” out of you. They also speed on the trails and do not have good control of their bikes.
(3) I have enough difficulty on the authorized paved hike and bike trails trying to bird watch or nature study, while dodging inconsiderate bikers too oblivious to issue an approaching warning.
(4) Much of the scenic opportunity seems lost on cyclists who are more concerned with how fast they can get from point A to point B.
(5) Mountain bikers consider themselves renegades with justified use of all public land with impunity.
Some commenters expressed specific concerns that off-road bicycles disrupt the quiet and tranquility of the hiking experience.
(1) Bicyclists inevitably . . . disrupt the peace and tranquility that comes with a National Park experience.
(2) Biking in pristine areas takes away the beauty and quiet of the area.
(3) The serenity and tranquility have forever been transformed into the BMX race course.
(4) Please do not allow mountain bikes in the Cuyahoga Valley Park. It will ruin the sublime, quiet nature of the park, at the expense of walkers and joggers.
Many commenters expressed concerns regarding the costs of long-term maintenance of trails. Some concerns were related to there being enough or too many trails in the park already. Comments also included concerns about prioritization of trail work, suggesting more emphasis on improving existing trails before building new trails. Two commenters specifically mentioned that the Old Carriage Trail bridges should be replaced.
(1) No money should be spent on these new trails until the Bridges on the Old Carriage Trail have been replaced.
(2) You don't seem to be able to maintain the trails that you have now. Much of the buckeye trail through the park would greatly benefit from stabilization projects.
(3) I would . . . request that before proceeding with actual trail construction CUVA consider adopting a method, open for public comment, for determining the priority in which proposed trail changes set forth in the Trail Plan are to be implemented.
(4) I just think that preexisting trails are sufficient and there is no need to create more. Sticking to preexisting trails . . . will not significantly increase trail maintenance as the creation of new trails would.
Some commenters expressed concerns that allowing off-road bicycles outside of developed areas was inconsistent with the mission of the NPS and of the CUVA.
(1) Thought the national park systems were created to preserve the natural biological systems remaining in this land, and not provide an outlet for mechanized thrill seekers. Authorizing such activities is not in keeping with the intent of the national park system, and I urge you to severely limit, or totally ban any such activities on park lands.
(2) The purpose of the park is to preserve nature and enjoy it—not to damage it with deep ruts that create more erosion and mud, etc.
(3) The primary purpose of the national park system is to PRESERVE those remaining bits of wildlife habitat, so that all future generations will still be able to experience it. You are failing to adhere to your mission.
(4) Is the CUVA's main attraction really “trails”? And should the park want to be characterized that way? What is the desired experience for visitors from other states, for locals who walk or bike casually in the park, for suburban/urban families who visit on weekends? How does the CUVA make itself different from a state park or a metropark or a national recreation area?
After consideration of the public comments, and additional review, the NPS has determined that one substantive change is necessary in the final rule: Removal of the High Meadow Trail from consideration as an off-road bicycle trail. This trail is designated as a cross-country ski trail, with conditional status as a potential off-road bicycle trail. Because no other conditional trails are included in this rule, and the use of High Meadow Trail for off-road bicycles is contingent on other conditional trails being established, this trail location is being withdrawn from and will not be authorized for bicycle use in this final rule.
To provide visitors with additional recreational bicycling opportunities and in compliance with the provisions of 36 CFR 4.30, this rule will allow the Superintendent to authorize bicycle use on all or portions of each of the following trails:
After trail construction is completed, but before a trail is authorized for bicycle use, the Superintendent will be required to issue a written determination that the trail is open for public use and that bicycle use is consistent with the TMP/EIS, including implementation of the park's sustainable trail guidelines with monitoring and mitigation through adaptive management. This will ensure that bicycle use remains consistent with the protection of the park area's natural, scenic and aesthetic values, safety considerations and management objectives, and will not disturb wildlife or park resources. No additional NEPA compliance would be necessary beyond the TMP/EIS ROD, and the written determination will be added into the park's administrative file for the trail project. The Superintendent will provide public notice when trail(s) are authorized for bicycle use through one or more of the procedures under 36 CFR 1.7.
The final rule also authorizes the Superintendent to establish conditions, impose closures, or restrictions for bicycle use on authorized trails, after taking into consideration public health and safety, resource protection, and other management activities and objectives, provided public notice is given under 36 CFR 1.7.
Executive Order 12866 provides that the Office of Information and Regulatory Affairs in the Office of Management and Budget will review all significant rules. The Office of Information and Regulatory Affairs has determined that this rule is not significant.
Executive Order 13563 reaffirms the principles of E.O. 12866 while calling for improvements in the nation's regulatory system to promote predictability, to reduce uncertainty, and to use the best, most innovative, and least burdensome tools for achieving regulatory ends. The executive order directs agencies to consider regulatory approaches that reduce burdens and maintain flexibility and freedom of choice for the public where these approaches are relevant, feasible, and consistent with regulatory objectives. E.O. 13563 emphasizes further that regulations must be based on the best available science and that the rulemaking process must allow for public participation and an open exchange of ideas. We have developed this rule in a manner consistent with these requirements.
This rule will not have a significant economic effect on a substantial number of small entities under the RFA (5 U.S.C. 601
This rule is not a major rule under 5 U.S.C. 804(2), the SBREFA. This rule:
a. Does not have an annual effect on the economy of $100 million or more.
b. Would not cause a major increase in costs or prices for consumers, individual industries, Federal, State, or local government agencies, or geographic regions.
c. Does not have significant adverse effects on competition, employment, investment, productivity, innovation, or the ability of U.S.-based enterprises to compete with foreign-based enterprises.
The current and anticipated users of bicycle routes in CUVA are predominantly individuals engaged in recreational activities. There are no businesses in the surrounding area that would be adversely affected by bicycle use of these trails. Although the park does not have any bicycle rental concessioners, there is a bicycle rental facility adjacent to the park that provides bike rentals that are used within CUVA.
This rule does not impose an unfunded mandate on State, local, or tribal governments or the private sector of more than $100 million per year. The rule does not have a significant or unique effect on State, local or tribal governments or the private sector. A statement containing the information required by the UMRA (2 U.S.C. 1531
This rule does not affect a taking of private property or otherwise have taking implications under Executive Order 12630. A taking implications assessment is not required because this rule will not deny any private property owner of beneficial uses of their land, nor will it significantly reduce their land's value.
Under the criteria in section 1 of Executive Order 13132, this rule does not have sufficient federalism implications to warrant the preparation of a Federalism summary impact statement. A Federalism summary impact statement is not required.
This rule complies with the requirements of Executive Order 12988. Specifically this rule:
(a) meets the criteria of section 3(a) requiring that all regulations be reviewed to eliminate errors and ambiguity and be written to minimize litigation; and
(b) meets the criteria of section 3(b)(2) requiring that all regulations be written in clear language and contain clear legal standards.
The Department of the Interior strives to strengthen its government-to-government relationship with Indian Tribes through a commitment to consultation with Indian Tribes and recognition of their right to self-governance and tribal sovereignty. We have evaluated this rule under the Department's consultation policy and under the criteria in Executive Order 13175 and have determined that it has no substantial direct effects on federally recognized Indian tribes and that consultation under the Department's tribal consultation policy is not required. Affiliated Native American tribes were contacted by letters sent in June, 2012 and May, 2013 to solicit any interests or concerns with the proposed action. No responses were received by the Park.
This rule does not contain information collection requirements, and a submission to the Office of Management and Budget under the PRA is not required.
We have prepared an environmental impact statement and have determined that this rule will not have a significant effect on the quality of the human environment under the NEPA of 1969. The TMP/EIS for the Park and ROD that included an evaluation of bicycling within the proposed areas may be viewed online at
This rule is not a significant energy action under the definition in Executive Order 13211. A statement of Energy Effects is not required.
The primary authors of this regulation are Lynn Garrity, and Kim Norley, Cuyahoga Valley National Park, and C. Rose Wilkinson and A.J. North, NPS Regulations Program, Washington, DC.
National Parks, Reporting and recordkeeping requirements.
In consideration of the foregoing, the NPS amends 36 CFR part 7 as set forth below:
54 U.S.C. 100101, 100751, 320102; Sec. 7.96 also issued under D.C. Code 10-137 and D.C. Code 50-2201.07.
(b)
(i) East Rim (approximately 10 miles);
(ii) Old Carriage Connector Trail (approximately 0.35 miles); and
(iii) Highland Connector Trail (approximately 1.0 mile).
(2) After trail construction is complete:
(i) To authorize bicycle use, the Superintendent must make a written determination that:
(A) The trail is open for public use; and
(B) Bicycle use is consistent with the protection of the park area's natural, scenic and aesthetic values, safety considerations, and management objectives, and will not disturb wildlife or park resources.
(ii) The Superintendent will provide public notice of all such actions through one or more of the methods listed in § 1.7 of this chapter.
(3) The Superintendent may open or close authorized trails, or portions thereof, or impose conditions or restrictions for bicycle use after taking into consideration public health and safety, natural and cultural resource protection, and other management activities and objectives.
(i) The Superintendent will provide public notice of all such actions through one or more of the methods listed in § 1.7 of this chapter.
(ii) Violating a closure, condition, or restriction is prohibited.
Environmental Protection Agency.
Final rule.
The Environmental Protection Agency (EPA) is taking final action to partially approve and disapprove elements of a State Implementation Plan (SIP) submission from the State of Nebraska addressing the applicable requirements of Clean Air Act (CAA) section 110 for the 1997 and 2006 National Ambient Air Quality Standards (NAAQS) for fine particulate matter (PM
This final rule is effective September 28, 2015.
EPA has established a docket for this action under Docket ID No. EPA-R07-OAR-2015-0269. All documents in the electronic docket are listed in the
Mr. Gregory Crable, Air Planning and Development Branch, U.S. Environmental Protection Agency, Region 7, 11201 Renner Boulevard, Lenexa, KS 66219;
Throughout this document, the terms “we,” “us,” or “our” refer to EPA. This section provides additional information by addressing the following:
On May 28, 2015, (80 FR 30404), EPA published a notice of proposed rulemaking (NPR) for the State of Nebraska. The NPR proposed partial approval and disapproval of Nebraska's submission that provides the basic elements specified in section 110(a)(2) of the CAA, or portions thereof, necessary to implement, maintain, and enforce the 1997 and 2006 PM
On April 3, 2008, EPA received a SIP submission from the state of Nebraska that addressed the infrastructure elements specified in section 110(a)(2) for the 1997 PM
Finally, a third submission was received by the EPA on November 14, 2011, as a part of a larger submission dealing with various title 129 revisions, which we will address at a later date. This submission revises Chapter 4, Title 129 of the Nebraska Administrative Code. The change repeals the annual NAAQS for PM
EPA is approving Nebraska's April 3, 2008, and August 29, 2011, submissions for the 1997 and 2006 PM
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 Nebraska regulations for Ambient Air Quality Standards and the EPA approved Nebraska nonregulatory provisions described in the amendments to 40 CFR part 52 set forth below. EPA has made, and will continue to make, these documents generally available electronically through
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, 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);
• 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 (Public Law 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 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).
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 CAA, petitions for judicial review of this action must be filed in the United States Court of Appeals for the appropriate circuit by October 26, 2015. 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, Particulate matter, Reporting and recordkeeping requirements.
For the reasons stated in the preamble, EPA amends 40 CFR part 52 as set forth below:
42 U.S.C. 7401
The revisions and additions read as follows:
(c) * * *
(e) * * *
Environmental Protection Agency.
Direct final rule.
The Environmental Protection Agency (EPA) is taking direct final action to approve an element of a State Implementation Plan (SIP) submission from the State of Kansas addressing the applicable requirements of Clean Air Act (CAA) section 110 for the 2008 National Ambient Air Quality Standards (NAAQS) for Ozone (O
This direct final rule will be effective October 26, 2015, without further notice, unless EPA receives adverse comment by September 28, 2015. If EPA receives adverse comment, we will publish a timely withdrawal of the direct final rule in the
Submit your comments, identified by Docket ID No. EPA-R07-OAR-2015-0512, by one of the following methods:
1.
2.
3.
Lachala Kemp, Environmental Protection Agency, Air Planning and Development Branch, 11201 Renner Boulevard, Lenexa, Kansas 66219 at (913) 551-7214 or by email at
Throughout this document whenever “we”, “us”, or “our” is used, we refer to EPA. This section provides additional information by addressing the following questions:
On July 16, 2014, (79 FR 41486), EPA published a notice of proposed rulemaking (NPR) for the State of Kansas. The NPR proposed approval of Kansas' submission that provides the basic elements specified in section 110(a)(2) of the CAA, or portions thereof, necessary to implement, maintain, and enforce the 2008 O
On March 19, 2013, and May 9, 2013, EPA received SIP submissions from the state of Kansas that address the infrastructure elements specified in section 110(a)(2) of the CAA for the 2008 O
Under section 110(a)(2)(J) of the CAA, states are required to submit SIPs that meet, among other provisions, part C of the CAA, relating to prevention of significant deterioration of air quality and visibility protection. With respect to the visibility component of section 110(a)(2)(J) of the CAA, Kansas stated in its 2008 O
EPA recognizes that states are subject to visibility and regional haze program requirements under part C of the CAA. However, when EPA establishes or revises a NAAQS, these visibility and regional haze requirements under part C
EPA is taking direct final action to approve the visibility protection portion of section 110(a)(2)(J) of the CAA with regard to the March 19, 2013, and May 9, 2013, infrastructure SIP submissions from the state of Kansas.
Based upon review of the state's infrastructure SIP submissions and relevant statutory and regulatory authorities and provisions referenced in the submission or referenced in Kansas' SIP, EPA is approving Kansas' SIP submittals as they satisfy the applicable visibility requirements of section 110(a)(2)(J) of the CAA with respect to the 2008 O
We are publishing this direct final rule without a prior proposed rule because we view this as a noncontroversial action and anticipate no adverse comment. However, in the “Proposed Rules” section of this
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, EPA's role is to approve state choices, provided that they meet the criteria of the Clean Air 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);
• 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 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).
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 CAA, petitions for judicial review of this action must be filed in the United States Court of Appeals for the appropriate circuit by October 26, 2015. 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, Ozone, Reporting and recordkeeping requirements.
For the reasons stated in the preamble, EPA amends 40 CFR part 52 as set forth below:
42 U.S.C. 7401
(e) * * *
National Aeronautics and Space Administration.
Interim rule.
The National Aeronautics and Space Administration (NASA) is issuing an interim rule amending the NASA FAR Supplement to increase the NASA capitalization threshold from $100,000 to $500,000.
Interested parties may submit comments identified by NFS Case 2015-N004, using any of the following methods:
○
○
○
○
Andrew O'Rourke, NASA Office of Procurement, Contract and Grant Policy Division, 202-358-4560, email:
In accordance with the Statement of Federal Financial Accounting Standard (SFFAS) No. 6, Accounting for Property, Plant, and Equipment, federal agencies are to record as property and equipment all items that meet certain characteristics, such as a useful life of 2 years or more, and are permitted to establish individual capitalization thresholds and useful life policies due to their diverse size and uses of property, plant & equipment. SFFAS No. 6 was issued in November 1995 and was effective for fiscal years beginning after September 30, 1997. The current NASA capitalization threshold of $100,000, was established when SFFAS 6 was initially implemented and is in the NFS.
The Government Accountability Office (GAO) recommends that capitalization thresholds should be periodically reevaluated to help ensure their continuing relevance and are tied to materiality as well, in that they generally are established at a level that would not omit a significant amount of assets from the balance sheet, which could materially misstate the financial statements of an entity or its components.
Recently, the NASA Office of the Chief Financial Officer conducted a review of the current NASA capitalization threshold of $100,000 and based on this review it was determined to increase the capitalization threshold from $100,000 to $500,000.
This interim rule revises NFS parts 1845 and 1852 by increasing an already established NASA capitalization threshold from $100,000 to $500,000. Specifically, the proposed changes are as follows:
• Added a new paragraph (b) to section 1845.301-71.
• Changed capitalization threshold amount from $100,000 to $500,000 in sections 1845.7101-1, 1845.7101-2, 1845.7101-3, 1852.245-70, and 1852.245-78.
Executive Orders (E.O.s) 12866 and 13563 direct agencies to assess all costs and benefits of available regulatory alternatives and, if regulation is necessary, to select regulatory approaches that maximize net benefits (including potential economic, environmental, public health and safety effects, distributive impacts, and equity). E.O. 13563 emphasizes the importance of quantifying both costs and benefits, of reducing costs, of harmonizing rules, and of promoting flexibility. This rule is not a significant regulatory action under section 3(f) of Executive Order 12866. This rule is not a major rule under 5 U.S.C. 804.
NASA does not expect this interim rule to have a significant economic impact on a substantial number of small entities within the meaning of the Regulatory Flexibility Act, 5 U.S.C. 601,
The increase in the NASA capitalization threshold is expected to benefit NASA contractors by reducing the administrative burden associated with financial reporting of NASA property in the custody of contractors. The legal basis for this rule is 51 U.S.C. 20113(a).
The requirements under this rule will apply to any contract award (including contracts for supplies, services, construction, and major systems) that
The rule does not duplicate, overlap, or conflict with any other Federal rules. No alternatives were identified that would meet the objectives of the rule.
NASA invites comments from small business concerns and other interested parties on the expected impact of this rule on small entities. NASA will also consider comments from small entities concerning the existing regulations in subparts affected by this rule in accordance with 5 U.S.C. 610. Interested parties must submit such comments separately and should cite 5 U.S.C. 610 (NASA Case 2015-N004), in correspondence.
The Paperwork Reduction Act (Pub. L. 104-13) is applicable. However, the NFS changes do not impose information collection requirements that require the approval of the Office of Management and Budget under 44 U.S.C. 3501,
A determination has been made by the Assistant Administrator for Procurement, pursuant to 41 U.S.C. 1707(d) that urgent and compelling reasons exist to justify promulgating this rule on an interim basis without prior opportunity for public comment. This interim rule is needed to prevent the continuation of the mandate of contractors having to submit reports at the current threshold specified in the NASA FAR Supplement while the NASA Financial Regulation requires reporting at a higher dollar threshold. This inconsistency of reporting threshold results in contractors incurring costs of reporting unnecessary information at taxpayer expense. Immediate implementation of this rule will reduce superfluous reporting burdens to contractors resulting in savings to both contractor and the Government. By increasing the NASA capitalization threshold, we estimate a reduction in reporting of 320 assets resulting in an annual decrease in burden of 1,920 hours and approximately $148,000 in cost avoidance.
The current NASA capital asset threshold of $100,000 was established when Statement of Federal Financial Accounting Standard (SFFAS) No. 6, Accounting for Property, Plant, and Equipment was initially implemented in 1997 and has not been adjusted in the NFS since that time. The Government Accountability Office (GAO) recommends that capital asset thresholds should be periodically reevaluated to ensure their continuing relevance and that they are established at a level that would not omit a significant amount of assets from the balance sheet. As such the NASA Office of the Chief Financial Officer conducted a review of the current NASA capital asset threshold of $100,000 and based on this review determined an increase in the capital asset threshold to $500,000 was warranted per NASA Interim Directive (NID) for NPR 9250.1, Property, Plant, and Equipment and Operating Materials and Supplies.
The most effective and efficient way to ensure awareness of and compliance by contractors with this increase to the capital asset threshold reporting requirement is through an immediate regulatory change. Delaying promulgation of this increase to the capital asset threshold would cause contractors to continue reporting such assets at the lower threshold effectively maintaining this unnecessary administrative burden on the contractor and delaying contractor savings that would come from this reduced reporting requirement. Moreover, contractors would be providing information on capital assets that would not be used by NASA since the NID implementing this capital asset threshold increase within the NASA financial community is already in effect. Pursuant to 41 U.S.C. 1707 and FAR 1.501-3(b), NASA will consider public comments received in response to this interim rule in the formation of the Agency's final rule.
Government procurement.
Accordingly, 48 CFR parts 1845 and 1852 are amended as follows:
51 U.S.C. 20113(a) and 41 U.S.C. chapter 1.
(b)(1) The Center Procurement Officer is the approval authority for non-Government use of equipment exceeding 25 percent.
(2) The percentage of Government and non-Government use shall be computed on the basis of time available for use. For this purpose, the contractor's normal work schedule, as represented by scheduled production shift hours, shall be used. All equipment having a unit acquisition cost of less than $500,000 at any single location may be averaged over a quarterly period. Equipment having a unit acquisition cost of $500,000 or more shall be considered on an item-by-item basis.
(3) Approvals for non-Government use, less than 25 percent, may not exceed 1 year. Approval for non-Government use in excess of 25 percent shall not exceed 3 months.
(4) Requests for the approval shall be submitted to the Center Procurement Officer at least 6 weeks in advance of the projected use and shall include—
(i) The number of equipment items involved and their total acquisition cost; and
(ii) An itemized listing of equipment having an acquisition cost of $500,000 or more, showing for each item the nomenclature, year of manufacture, and acquisition cost.
(f) Only modifications that improve an item's capacity or extend its useful life two years or more and that cost $500,000 or more shall be reported on the NF 1018 on the $500,000 & Over line. The costs of any other modifications, excluding routine maintenance, will be reported on the Under $500,000 line. If an item's original unit acquisition cost is less than $500,000, but a single subsequent modification costs $500,000 or more, that modification only will be reported as an item $500,000 or more on subsequent NF 1018s. The original acquisition cost of the item will
51 U.S.C. 20113(a) and 41 U.S.C. chapter 1.
(b) * * *
(1) * * *
(iv) Combine requests for quantities of items with identical descriptions and estimated values when the estimated values do not exceed $500,000 per unit; and
(v) Include only a single unit when the acquisition or construction value equals or exceeds $500,000.
As prescribed in 1845.107-70(a)(2), add the following paragraph (e).
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Temporary rule; inseason General category retention limit adjustment.
NMFS is adjusting the Atlantic bluefin tuna (BFT) General category daily retention limit from the default limit of one large medium or giant BFT to four large medium or giant BFT for the September, October through November, and December subquota time periods of the 2015 fishing year. This action is based on consideration of the regulatory determination criteria regarding inseason adjustments, and applies to Atlantic tunas General category (commercial) permitted vessels and Highly Migratory Species (HMS) Charter/Headboat category permitted vessels when fishing commercially for BFT.
Effective September 1, 2015, through December 31, 2015.
Sarah McLaughlin or Brad McHale, 978-281-9260.
Regulations implemented under the authority of the Atlantic Tunas Convention Act (ATCA; 16 U.S.C. 971
The currently codified baseline U.S. quota is 923.7 mt (not including the 25 mt ICCAT allocated to the United States to account for bycatch of BFT in pelagic longline fisheries in the Northeast Distant Gear Restricted Area). Among other things, Amendment 7 revised the allocations to all quota categories, effective January 1, 2015. See § 635.27(a). The currently codified General category quota is 403 mt. Each of the General category time periods (“January,” June through August, September, October through November, and December) is allocated a portion of the annual General category quota. The codified baseline General category subquotas include 106.8 mt for September, 52.4 mt for October through November, and 21 mt for December. NMFS transferred 21 mt of BFT quota from the December 2015 subquota to the January 2015 subquota period (79 FR 77943, December 29, 2014).
Unless changed, the General category daily retention limit starting on September 1 would be the default retention limit of one large medium or giant BFT (measuring 73 inches (185 cm) curved fork length (CFL) or greater) per vessel per day/trip (§ 635.23(a)(2)). This default retention limit would apply to General category permitted vessels and to HMS Charter/Headboat category permitted vessels when fishing commercially for BFT.
For the 2014 fishing year, NMFS adjusted the General category limit from the default level of one large medium or giant BFT as follows: Two large medium or giant BFT for January (78 FR 77362, December 23, 2013), four large medium or giant BFT for June through August (79 FR 30745, May 29, 2014), and four large medium or giant BFT for September through December (79 FR 50854, August 26, 2014). NMFS adjusted the daily retention limit for the 2015 January subquota period from the default level of one large medium or giant BFT to three large medium or giant BFT in the same action as the 21-mt transfer from the December 2015 subquota period to the January 2015 subquota period described above (79 FR 77943, December 29, 2014). For the June through August 2015 subquota period, NMFS adjusted the daily retention limit to four large medium or giant BFT (80 FR 27863, May 15, 2015).
Under § 635.23(a)(4), NMFS may increase or decrease the daily retention limit of large medium and giant BFT over a range of zero to a maximum of five per vessel based on consideration of the relevant criteria provided under § 635.27(a)(8), which are: The usefulness of information obtained from catches in the particular category for biological sampling and monitoring of the status of the stock; the catches of the particular category quota to date and the likelihood of closure of that segment of the fishery if no adjustment is made; the projected ability of the vessels fishing under the particular category quota to harvest the additional amount of BFT before the end of the fishing year; the estimated amounts by which quotas for other gear categories of the fishery might be exceeded; effects of the adjustment on BFT rebuilding and overfishing; effects of the adjustment on accomplishing the objectives of the fishery management plan; variations in seasonal distribution, abundance, or migration patterns of BFT; effects of catch rates in one area precluding vessels in another area from having a reasonable opportunity to harvest a portion of the category's quota; review of dealer reports, daily landing trends, and the availability of the BFT on the fishing grounds; optimizing fishing opportunity; accounting for dead discards, facilitating quota monitoring, supporting other fishing monitoring programs through quota allocations and/or generation of revenue; and support of research through quota allocations and/or generation of revenue.
NMFS has considered these criteria and their applicability to the General category BFT retention limit for September through December 2015. These include, but are not limited to, the following considerations: Biological samples collected from BFT landed by General category fishermen and provided by BFT dealers continue to provide NMFS with valuable data for ongoing scientific studies of BFT age and growth, migration, and reproductive status. Continued BFT landings would support the collection of a broad range of data for these studies and for stock monitoring purposes.
As this action would be taken consistent with the quotas previously established and analyzed in Amendment 7 (79 FR 71510, December 2, 2014), and consistent with objectives of the 2006 Consolidated HMS FMP, it is not expected to negatively impact stock health. A principal consideration is the objective of providing opportunities to harvest the full 2015 General category quota without exceeding it based upon the 2006 Consolidated HMS FMP goal: “Consistent with other objectives of this FMP, to manage Atlantic HMS fisheries for continuing optimum yield so as to provide the greatest overall benefit to the Nation, particularly with respect to food production, providing recreational opportunities, preserving traditional fisheries, and taking into account the protection of marine ecosystems.” It is also important that NMFS constrain landings to BFT subquotas both to adhere to the FMP quota allocations and to ensure that landings are as consistent as possible with the pattern of fishing mortality (
NMFS also considered the fact that it has prepared a final quota rule that would implement and give domestic effect to the 2014 ICCAT recommendation on western Atlantic BFT management, which increased the U.S. BFT quota for 2015 and 2016 by 14 percent from the 2014 level (proposed rule: 80 FR 33467, June 12, 2015; final rule expected to file with the Office of the Federal Register in late August and be effective in late September 2015). The domestic subquotas in that action would result from application of the allocation process established in Amendment 7 to the increased U.S. quota, and would include an increase in the General category quota from the currently codified 403 mt to 466.7 mt. As explained below, however, the retention limits being set in this action are not dependent on those quota increases.
Commercial-sized BFT migrated to the fishing grounds off New England by early June and are actively being landed. As of August 14, 2015, 141.5 mt of the 2015 General category quota of 403 mt have been landed, and landings rates remain at approximately 1 mt per day. Given the rollover of unused quota from one time period to the next, current catch rates, and the fact that the daily retention limit will automatically revert to one large medium or giant BFT per vessel per day on September 1, 2015, absent agency action, NMFS anticipates the full 2015 General category quota may not be harvested. In September through December 2014, under a four-fish limit, BFT landings were approximately 268.4 mt. For the entire 2014 fishing year, 94.6 percent of the available General category quota was filled.
A limit lower than four fish could result in unused quota being added to the later portion of the General category season (
Based on these considerations, NMFS has determined that a four-fish General category retention limit is warranted. It would provide a reasonable opportunity to harvest the U.S. BFT quota, without exceeding it, while maintaining an equitable distribution of fishing opportunities; help achieve optimum yield in the BFT fishery; allow the collection of a broad range of data for stock monitoring purposes; and be consistent with the objectives of the 2006 Consolidated HMS FMP, as amended. Therefore, NMFS increases the General category retention limit from the default limit (one) to four large medium or giant BFT per vessel per day/trip, effective September 1, 2015, through December 31, 2015.
Regardless of the duration of a fishing trip, the daily retention limit applies upon landing. For example (and specific to the September through December 2015 limit), whether a vessel fishing under the General category limit takes a two-day trip or makes two trips in one day, the daily limit of four fish may not be exceeded upon landing. This General category retention limit is effective in all areas, except for the Gulf of Mexico, where NMFS prohibits targeting fishing for BFT, and applies to those vessels permitted in the General category, as well as to those HMS Charter/Headboat permitted vessels fishing commercially for BFT.
NMFS will continue to monitor the BFT fishery closely through the landings and catch reports. Dealers are required to submit landing reports within 24 hours of a dealer receiving
Closures or subsequent adjustments to the daily retention limits, if any, will be published in the
The Assistant Administrator for NMFS (AA) finds that it is impracticable and contrary to the public interest to provide prior notice of, and an opportunity for public comment on, this action for the following reasons.
The regulations implementing the 2006 Consolidated HMS FMP, as amended, provide for inseason retention limit adjustments to respond to the unpredictable nature of BFT availability on the fishing grounds, the migratory nature of this species, and the regional variations in the BFT fishery. Based on available BFT quotas, fishery performance in recent years, the availability of BFT on the fishing grounds, among other considerations, adjustment to the General category BFT daily retention limit from the default level is warranted. Analysis of available data shows that adjustment to the BFT daily retention limit from the default level would result in minimal risks of exceeding the ICCAT-allocated quota. NMFS provides notification of retention limit adjustments by publishing the notice in the
Delays in increasing these retention limits would adversely affect those General and Charter/Headboat category vessels that would otherwise have an opportunity to harvest more than the default retention limit of one BFT per day/trip and may exacerbate the problem of low catch rates and quota rollovers. Limited opportunities to harvest the respective quotas may have negative social and economic impacts for U.S. fishermen that depend upon catching the available quota within the time periods designated in the 2006 Consolidated HMS FMP, as amended. Adjustment of the retention limit needs to be effective September 1, 2015, or as soon as possible thereafter, to minimize any unnecessary disruption in fishing patterns, to allow the impacted sectors to benefit from the adjustment, and to not preclude fishing opportunities for fishermen in geographic areas with access to the fishery only during this time period. Therefore, the AA finds good cause under 5 U.S.C. 553(b)(B) to waive prior notice and the opportunity for public comment. For these reasons, there is good cause under 5 U.S.C. 553(d) to waive the 30-day delay in effectiveness.
This action is being taken under § 635.23(a)(4) and is exempt from review under Executive Order 12866.
16 U.S.C. 971
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Temporary rule.
NMFS is reallocating the projected unused amounts of the Aleut Corporation's pollock directed fishing allowance from the Aleutian Islands subarea to the Bering Sea subarea directed fisheries. This action is necessary to provide opportunity for harvest of the 2015 total allowable catch of pollock, consistent with the goals and objectives of the Fishery Management Plan for Groundfish of the Bering Sea and Aleutian Islands Management Area.
Effective 1200 hrs, Alaska local time (A.l.t.), August 27, 2015, until 2400 hrs, A.l.t., December 31, 2015.
Steve Whitney, 907-586-7228.
NMFS manages the groundfish fishery in the BSAI exclusive economic zone according to the Fishery Management Plan for Groundfish of the Bering Sea and Aleutian Islands Management Area (FMP) prepared by the North Pacific Fishery Management Council (Council) under authority of the Magnuson-Stevens Fishery Conservation and Management Act. Regulations governing fishing by U.S. vessels in accordance with the FMP appear at subpart H of 50 CFR part 600 and 50 CFR part 679.
In the Aleutian Islands subarea, the portion of the 2015 pollock total allowable catch (TAC) allocated to the Aleut Corporation's directed fishing allowance (DFA) is 12,146 metric tons (mt) as established by the final 2015 and 2016 harvest specifications for groundfish in the BSAI (80 FR 11919, March 5, 2015), and through reallocation (80 FR 15695, March 25, 2015).
As of August 19, 2015, the Administrator, Alaska Region, NMFS, (Regional Administrator) has determined that 10,000 metric tons (mt) of Aleut Corporation's DFA will not be harvested. Therefore, in accordance with § 679.20(a)(5)(iii)(B)(
This action responds to the best available information recently obtained from the fishery. The Assistant Administrator for Fisheries, NOAA (AA), finds good cause to waive the requirement to provide prior notice and opportunity for public comment pursuant to the authority set forth at 5 U.S.C. 553(b)(B) as such requirement is impracticable and contrary to the public interest. This requirement is impracticable and contrary to the public interest as it would prevent NMFS from responding to the most recent fisheries data in a timely fashion and would delay the reallocation of AI pollock. Since the pollock fishery is currently open, it is important to immediately inform the industry as to the final Bering Sea subarea pollock allocations. Immediate notification is necessary to allow for the orderly conduct and efficient operation of this fishery; allow the industry to plan for the fishing season and avoid potential disruption to the fishing fleet as well as processors; and provide opportunity to harvest increased seasonal pollock allocations while value is optimum. NMFS was unable to publish a notice providing time for public comment because the most recent, relevant data only became available as of August 19, 2015.
The AA also finds good cause to waive the 30-day delay in the effective date of this action under 5 U.S.C. 553(d)(3). This finding is based upon the reasons provided above for waiver of prior notice and opportunity for public comment.
This action is required by § 679.20 and is exempt from review under Executive Order 12866.
16 U.S.C. 1801
U.S. Office of Personnel Management.
Proposed rule with request for comments.
The U.S. Office of Personnel Management (OPM) is issuing a proposed rule that would define Hancock County, Mississippi, as an area of application county to the Harrison, MS, nonappropriated fund (NAF) Federal Wage System (FWS) wage area. This change is necessary because there are four NAF FWS employees working in Hancock County, and the county is not currently defined to a NAF wage area.
We must receive comments on or before September 28, 2015.
You may submit comments, identified by “RIN 3206-AN20,” using any of the following methods:
Madeline Gonzalez, by telephone at (202) 606-2858 or by email at
OPM is issuing a proposed rule that would define Hancock County, MS, as an area of application to the Harrison, MS, NAF FWS wage area. The Navy Exchange and Navy Morale, Welfare, and Recreation in Hancock County is now operating NAF activities at the John C. Stennis Space Center, located in southwestern Mississippi, with a combined total of four NAF employees.
Under section 532.219 of title 5, Code of Federal Regulations, each NAF wage area “shall consist of one or more survey areas, along with nonsurvey areas, if any, having nonappropriated fund employees.” Hancock County does not meet the regulatory criteria under 5 CFR 532.219 to be established as a separate NAF wage area; however, nonsurvey counties may be combined with a survey area to form a wage area. Section 532.219 lists the regulatory criteria that OPM considers when defining FWS wage area boundaries:
• Proximity of largest facilities activity in each county;
• Transportation facilities and commuting patterns; and
• Similarities of the counties in:
○ Overall population,
○ Private employment in major industry categories, and
○ Kinds and sizes of private industrial establishments.
Based on an analysis of the regulatory criteria for defining NAF wage areas, Hancock County, MS, should be defined as an area of application to Harrison, MS, NAF FWS wage area. The proximity criterion favors the Harrison, MS, wage area more than the Orleans, LA, wage area. The transportation facilities criterion does not favor one wage area more than another. The commuting patterns criterion favors the Harrison wage area. Although the overall population, employment sizes, and kinds and sizes of private industrial establishments criterion does not favor one wage area more than another, the industrial distribution pattern for Hancock County is more similar to the Harrison survey area than to the Orleans survey area. While a standard review of regulatory criteria shows mixed results, the proximity and commuting patterns criteria solidly favor the Harrison wage area. Based on this analysis, we propose that Hancock County be defined to the Harrison NAF wage area.
The proposed expanded Harrison NAF wage area would consist of one survey county (Harrison County, MS) and four area of application counties (Mobile County, AL, and Forrest, Hancock, and Jackson Counties, MS). The Federal Prevailing Rate Advisory Committee, the national labor-management committee responsible for advising OPM on matters concerning the pay of FWS employees, recommended this change by consensus. This change would be effective on the first day of the first applicable pay period beginning on or after 30 days following publication of the final regulations.
I certify that these regulations would not have a significant economic impact on a substantial number of small entities because they would affect only Federal agencies and employees.
Administrative practice and procedure, Freedom of information, Government employees, Reporting and recordkeeping requirements, Wages.
Accordingly, the U.S. Office of Personnel Management is proposing to amend 5 CFR part 532 as follows:
5 U.S.C. 5343, 5346; § 532.707 also issued under 5 U.S.C. 552.
Nuclear Regulatory Commission.
Proposed rule and draft NUREG; reopening of comment period.
On March 26, 2015, the U.S. Nuclear Regulatory Commission (NRC) requested public comment on a proposed rule that would amend its regulations that govern low-level radioactive waste (LLRW) disposal facilities. The proposed rule would require new and revised site-specific technical analyses, permit the development of site-specific criteria for LLRW acceptance based on the results of those analyses, facilitate implementation, and better align the requirements with current health and safety standards. Also on March 26, 2015, the NRC requested comment on draft guidance to address the implementation of the proposed regulations (NUREG-2175, “Guidance for Conducting Technical Analyses for 10 CFR part 61”). The public comment period for the proposed rule and draft guidance closed on July 24, 2015. The NRC is reopening the public comment periods for the proposed rule and draft guidance to allow more time for members of the public to develop and submit their comments.
The comment periods for the proposed rule published on March 26, 2015 (80 FR 16081), and the draft guidance published on March 26, 2015 (80 FR 15930), have been reopened. Comments should be filed no later than September 21, 2015.
The methods for submitting comments on the proposed rule are different from the methods for submitting comments on the draft guidance.
Proposed Rule: You may submit comments on the proposed rule by any of the following methods:
•
•
•
•
•
Draft Guidance: You may submit comments on the draft guidance by any of the following methods:
•
•
Address questions about NRC dockets to Carol Gallagher; telephone: (301) 415-3463; email:
For additional direction on obtaining information and submitting comments, see “Obtaining Information and Submitting Comments” in the
Gary Comfort, telephone: (301) 415-8106, email:
Please refer to Docket ID NRC-2011-0012 (proposed rule) and Docket ID NRC-2015-0003 (draft guidance) when contacting the NRC about the availability of information for this action. You may obtain publicly-available information related to the proposed rule and draft guidance by any of the following methods:
•
•
•
Please include Docket ID NRC-2011-0012 (proposed rule) or Docket ID NRC-2015-0003 (draft guidance) 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.
On March 26, 2015 (80 FR 16081), the NRC requested comment on a proposed rule that would amend its regulations that govern LLRW disposal facilities to require new and revised site-specific technical analyses, to permit the development of site-specific criteria for LLRW acceptance based on the results of those analyses, to facilitate implementation, and to better align the requirements with current health and safety standards. Also on March 26, 2015 (80 FR 15930), the NRC requested comments on draft guidance to address the implementation of the proposed regulations (NUREG-2175, “Guidance for Conducting Technical Analyses for
For the Nuclear Regulatory Commission.
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
We propose to adopt a new airworthiness directive (AD) for all General Electric Company (GE) GEnx-1B54, -1B58, -1B64, -1B67, and -1B70 turbofan engine models. This proposed AD was prompted by reports of two in-flight shutdowns (IFSDs) caused by high-pressure turbine (HPT) rotor stage 1 blade failure. This proposed AD would require inspection and conditional removal of affected HPT rotor stage 1 blades. We are proposing this AD to prevent failure of the HPT rotor stage 1 blades, which could lead to failure of one or more engines, loss of thrust control, and damage to the airplane.
We must receive comments on this proposed AD by October 26, 2015.
You may send comments, using the procedures found in 14 CFR 11.43 and 11.45, by any of the following methods:
• Federal eRulemaking Portal: Go to
• Fax: 202-493-2251.
• Mail: U.S. Department of Transportation, Docket Operations, M-30, West Building Ground Floor, Room W12-140, 1200 New Jersey Avenue SE., Washington, DC 20590.
• Hand Delivery: Deliver to Mail address above between 9 a.m. and 5 p.m., Monday through Friday, except Federal holidays.
For service information identified in this proposed AD, contact General Electric Company, GE Aviation, Room 285, 1 Neumann Way, Cincinnati, OH 45215; phone: 513-552-3272; email:
You may examine the AD docket on the Internet at
Christopher McGuire, Aerospace Engineer, Engine Certification Office, FAA, Engine & Propeller Directorate, 12 New England Executive Park, Burlington, MA 01803; phone: 781-238-7120; fax: 781-238-7199; email:
We invite you to send any written relevant data, views, or arguments about this NPRM. Send your comments to an address listed under the
We will post all comments we receive, without change, to
We propose to adopt a new AD for all GE GEnx-1B54, -1B58, -1B64, -1B67, and -1B70 turbofan engine models. This proposed AD was prompted by reports of two IFSDs caused by HPT rotor stage 1 blade failure. This proposed AD would require inspection and conditional removal of affected HPT rotor stage 1 blades. This condition, if not corrected, could result in failure of the HPT rotor stage 1 blades, which could lead to failure of one or more engines, loss of thrust control, and damage to the airplane.
We reviewed GE GEnx-1B Service Bulletin (SB) No. 72-0267 R00, dated April 10, 2015. The SB describes procedures for borescope inspection (BSI) of the HPT rotor stage 1 blades.
We are proposing this NPRM 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 NPRM would require initial and repetitive BSI and conditional removal of affected HPT rotor stage 1 blades.
We estimate that this proposed AD will affect 4 engines installed on airplanes of U.S. registry. We also estimate that it will take about 2 hours per engine to comply with this proposed AD. The average labor rate is $85 per hour. Based on these figures, we estimate the total cost of this proposed AD to U.S. operators to be $680.
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
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 to the extent that it justifies making a regulatory distinction, 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 26, 2015.
None.
This AD applies to all General Electric Company (GE) GEnx-1B54, -1B58, -1B64, -1B67, and -1B70 turbofan engines with high-pressure turbine (HPT) rotor stage 1 blade, part number 2305M26P06, installed.
This AD was prompted by reports of two in-flight shutdowns caused by HPT rotor stage 1 blade failure. We are issuing this AD to prevent failure of the HPT rotor stage 1 blades, which could lead to failure of one or more engines, loss of thrust control, and damage to the airplane.
Comply with this AD within the compliance times specified, unless already done.
(1) After the effective date of this AD, perform an initial borescope inspection (BSI) of the convex surface of the HPT rotor stage 1 blades for axial cracks from the platform to 30% span, within 1,000 blade cycles since new or 25 cycles in service, whichever comes later, and disposition as follows:
(i) If any axial crack with a length greater than or equal to 0.3 inch is found, or if any axial crack of any length turning in a radial direction is found, or if more than one axial crack of any length is found, remove the cracked blade before further flight.
(ii) If an axial crack is found with a length greater than or equal to 0.2 inch and less than 0.3 inch, remove the cracked blade within 10 blade cycles in service.
(iii) If an axial crack is found with a length greater than or equal to 0.1 inch and less than 0.2 inch, inspect the cracked blade within 50 blade cycles since last inspection (CSLI).
(iv) If an axial crack is found with a length less than 0.1 inch, inspect the cracked blade within 100 blade CSLI.
(v) If no cracks were found, perform a BSI of the blades within 125 blade CSLI.
(2) Thereafter, perform a repetitive BSI of the convex surface of the HPT rotor stage 1 blades for axial cracks from the platform to 30% span within 125 blade CSLI and disposition as specified in (e)(1)(i) through (e)(1)(v), or remove the blades from service.
For the purpose of this AD, a “blade cycle” is defined as the number of engine cycles that a set of rotor blades has accrued, regardless of the engine(s) in which they have operated.
The Manager, Engine Certification Office, FAA, may approve AMOCs to this AD. Use the procedures found in 14 CFR 39.19 to make your request. You may email your request to:
(1) For more information about this AD, contact Christopher McGuire, Aerospace Engineer, Engine Certification Office, FAA, Engine & Propeller Directorate, 12 New England Executive Park, Burlington, MA 01803; phone: 781-238-7120; fax: 781-238-7199; email:
(2) GE GEnx-1B Service Bulletin No. 72-0267 R00, dated April 10, 2015 can be obtained from GE using the contact information in paragraph (h)(3) of this proposed AD.
(3) For service information identified in this proposed AD, contact General Electric Company, GE Aviation, Room 285, 1 Neumann Way, Cincinnati, OH 45215; phone: 513-552-3272; email:
(4) You may view this service information at the FAA, Engine & Propeller Directorate, 12 New England Executive Park, Burlington, MA. For information on the availability of this material at the FAA, call 781-238-7125.
Federal Aviation Administration (FAA), Department of Transportation (DOT).
Notice of proposed rulemaking (NPRM).
We propose to adopt a new airworthiness directive (AD) for certain Pacific Aerospace Limited Model 750XL airplanes that would supersede AD 2014-20-13. This proposed AD results from mandatory continuing airworthiness information (MCAI) originated by an aviation authority of another country to identify and correct an unsafe condition on an aviation product. The MCAI describes the unsafe condition as fatigue cracks on the fin forward pickup plates, which could cause it to fail. We are issuing this proposed AD to require actions to address the unsafe condition on these products.
We must receive comments on this proposed AD by October 13, 2015.
You may send comments by any of the following methods:
•
•
•
•
For service information identified in this proposed AD, contact Pacific Aerospace Limited, Airport Road, Hamilton, Private Bag 3027, Hamilton 3240, New Zealand, phone: +64 7 843 6144; fax: +64 7 843 6134; email:
You may examine the AD docket on the Internet at
Karl Schletzbaum, Aerospace Engineer, FAA, Small Airplane Directorate, 901 Locust, Room 301, Kansas City, Missouri 64106; telephone: (816) 329-4123; fax: (816) 329-4090; email:
We invite you to send any written relevant data, views, or arguments about this proposed AD. Send your comments to an address listed under the
We will post all comments we receive, without change, to
On September 26, 2014, we issued AD 2014-20-13, Amendment 39-17986 (79 FR 60329, October 7, 2014). That AD required actions intended to address an unsafe condition on all Pacific Aerospace Limited Model 750XL airplanes and was based on mandatory continuing airworthiness information (MCAI) originated by an aviation authority of another country.
Since we issued AD 2014-20-13, Amendment 39-17986 (79 FR 60329, October 7, 2014), Pacific Aerospace Limited has revised the related service information and developed a terminating action for the repetitive inspections.
The Civil Aviation Authority (CAA), which is the aviation authority for New Zealand, has issued AD DCA/750XL/18A, dated August 4, 2015 (referred to after this as “the MCAI”), to correct an unsafe condition for the specified products. The MCAI states:
DCA/750XL/18A revised to add note 2 and introduce minor editorial changes. This AD supersedes DCA/750XL/18 and DCA/750XL/16A to introduce the requirements in Pacific Aerospace Limited Mandatory Service Bulletin (MSB) PACSB/XL/068 issue 5, dated 29 June 2015. The revised MSB introduces a life limit for fin forward pickup P/N 11-10281-1 and reduces the torque setting for the fin forward pickup bolt to alleviate some of the loads applied to the pickup. The MSB also introduces a replacement fin forward pickup P/N 11-03375-1 which is not life limited.
You may examine the MCAI on the Internet at
Pacific Aerospace Limited has issued Mandatory Service Bulletin PACSB/XL/068, Issue 5, dated June 29, 2015. This service bulletin reduces the torque setting for the fin forward pickup bolt and introduces a new, improved replacement fin forward pickup plate, part number P/N 11-0375-1, to replace P/N 11-10281-1. 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 this State of Design Authority, they have notified us of the unsafe condition described in the MCAI and service information referenced above. We are proposing this AD because we evaluated all information and determined the unsafe condition exists and is likely to exist or develop on other products of the same type design.
We estimate that this proposed AD will affect 18 products of U.S. registry. We also estimate that it would take about 22 work-hours per product to comply with all the requirements of this proposed AD. The average labor rate is $85 per work-hour. Required parts would cost about $1,692 per product.
Based on these figures, we estimate the cost of the proposed AD on U.S. operators to be $64,116, or $3,562 per product.
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.
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 13, 2015.
This AD supersedes AD 2014-20-13, Amendment 39-17986 (79 FR 60329, October 7, 2014).
This AD applies to Pacific Aerospace Limited Model 750XL airplanes, all serial numbers through XL-193, XL-195, and XL-197, certificated in any category.
Air Transport Association of America (ATA) Code 53: Fuselage.
This AD was prompted by mandatory continuing airworthiness information (MCAI) originated by an aviation authority of another country to identify and correct an unsafe condition on an aviation product. The MCAI describes the unsafe condition as fatigue cracks on the fin forward pickup plates. We are issuing this AD to detect and correct cracked fin forward pickup plates to prevent failure of the fin forward pickup plates, which could result in reduced control.
Unless already done, do the actions in paragraphs (f)(1) through (f)(4) of this AD:
(1) Within the next 150 hours time-in-service (TIS) after the effective date of this AD, reduce the fin forward pickup bolt torque following the procedures in section 1.D., paragraphs A. 1) and A. 2) of the PLANNING INFORMATION in Pacific Aerospace Limited Mandatory Service Bulletin PACSB/XL/068, Issue 5, dated June 29, 2015.
(2) At or before reaching 2,000 hours total time-in-service (TTIS) or within the next 150 hours TIS after the effective date of this AD, whichever occurs later, and repetitively thereafter at intervals not to exceed 600 hours TIS or 12 months, whichever occurs first, do a detailed visual inspection and liquid penetrant inspection of the fin forward pickup plates for any evidence of cracking. Do the inspections following the procedures in sections 2.A. and 2.B. of the ACCOMPLISHMENT INSTRUCTIONS in Pacific Aerospace Limited Mandatory Service Bulletin PACSB/XL/068, Issue 5, dated June 29, 2015.
(3) If cracks are found during any inspection required in paragraph (f)(2) of this AD, before further flight, replace the fin forward pickup plates with new fin forward pickup plates, part number (P/N) 11-03375-1. Do the replacement following the procedures in section 2.C. of the ACCOMPLISHMENT INSTRUCTIONS in Pacific Aerospace Limited Mandatory Service Bulletin PACSB/XL/068, Issue 5, dated June 29, 2015. This replacement terminates the repetitive inspections required in paragraph (f)(2) of this AD.
(4) If no cracks are found during any inspection required in paragraph (f)(2) of this AD, at or before reaching 6,000 hours TTIS or within the next 600 hours TIS after the effective date of this AD, whichever occurs later, replace the fin forward pickup plates, P/N 11-10281-1, with P/N 11-03375-1. Do the replacement following the procedures in section 2.D. of the ACCOMPLISHMENT INSTRUCTIONS in Pacific Aerospace Limited Mandatory Service Bulletin PACSB/XL/068, Issue 5, dated June 29, 2015. This replacement terminates the repetitive inspections required in paragraph (f)(2) of this AD .
The following provisions also apply to this AD:
(1)
(2)
Refer to MCAI Civil Aviation Authority (CAA) AD DCA/750XL/18A, dated August 4, 2015, for related information. You may examine the MCAI on the Internet at
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
We propose to adopt a new airworthiness directive (AD) for certain Airbus Model A320-212, -214, -232, and -233 airplanes. This proposed AD was prompted by a report of a crack found during an inspection of the pocket radius of the fuselage frame. This proposed AD would require repetitive low frequency eddy current inspections or repetitive high frequency eddy current inspections of this area, and repair if necessary. The repair terminates the repetitive inspections. We are proposing this AD to detect and correct any cracking of the pocket radius, which could lead to in-flight decompression of the airplane and possible injury to the passengers.
We must receive comments on this proposed AD by October 13, 2015.
You may send comments, using the procedures found in 14 CFR 11.43 and 11.45, by any of the following methods:
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For service information identified in this proposed AD, contact Airbus, Airworthiness Office—EIAS, 1 Rond Point Maurice Bellonte, 31707 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 Branch, ANM-116, Transport Airplane Directorate, FAA, 1601 Lind Avenue SW., Renton, WA 98057-3356; telephone 425-227-1405; fax 425-227-1149.
We invite you to send any written relevant data, views, or arguments about this proposed AD. 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 Airworthiness Directive 2014-0278, dated December 19, 2014 (referred to after this as the Mandatory Continuing Airworthiness Information, or “the MCAI”), to correct an unsafe condition for certain Airbus Model A320-212, -214, -232, and -233 airplanes. The MCAI states:
An operator reported finding a crack during an inspection in accordance with the instructions of Airbus Alert Operators Transmission (AOT) A53N007-14. What was found, a 170 mm through-thickness crack in the pocket radius between frame 36 and 37 above stringer 6 on left hand (LH) side lap joint, was not the aim of the AOT inspection. Prior to this finding, the operator reported noise in the affected area during several weeks.
This condition, if not detected and corrected, could lead to in-flight decompression of the aeroplane, possibly resulting in injury to occupants.
To address this unsafe condition, Airbus published AOT A53N009-14 to provide inspection and repair instructions to detect and prevent crack propagation.
EASA decided to agree on a sampling inspection to determine whether additional aeroplanes need to be inspected.
For the reasons described above, this [EASA] AD requires, for the selected aeroplanes, repetitive Low Frequency Eddy Current (LFEC) or High Frequency Eddy Current (HFEC) inspections of the pocket radii [for cracks] located between fuselage frames 35 and 40, above stringer 6 on both LH and right hand (RH) sides and, depending on findings, accomplishment of repair instructions.
This [EASA] AD is considered an interim action and further [EASA] AD action may follow.
You may examine the MCAI in the AD docket on the Internet at
We reviewed Airbus Alert Operators Transmission A53N009-14, dated December 17, 2014. The service information describes procedures for repetitive inspections of the pocket radii located between fuselage frames 35 and 40, above stringer 6 on both the left- and right-hand sides, and repair if necessary. 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 pertinent information and determined an unsafe condition exists and is likely to exist or develop on other products of the same type design.
We estimate that this proposed AD affects 1 airplane of U.S. registry.
We also estimate that it would take about 3 work-hours per product to comply with the basic requirements of this proposed AD. The average labor rate is $85 per work-hour. Based on these figures, we estimate the cost of this proposed AD on U.S. operators to be $255, or $255 per product.
We have received no definitive data that would enable us to provide cost estimates for the on-condition actions specified in 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.
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 13, 2015.
None.
This AD applies to Airbus Model A320-212 airplanes having manufacturer serial number (MSN) 1011; Airbus Model A320-214 airplanes having MSNs 1009, 1026 and 1030; Airbus Model A320-232 airplanes having MSN 0977; and Airbus Model A320-233 airplanes having MSNs 1007 and 1013, certificated in any category.
Air Transport Association (ATA) of America Code 53, Fuselage.
This AD was prompted by a report of a crack found during an inspection of the pocket radius of the fuselage frame. We are issuing this AD to detect and correct any cracking of the pocket radius, which could lead to in-flight decompression of the airplane and possible injury to the passengers.
Comply with this AD within the compliance times specified, unless already done.
(1) Within 750 flight cycles or 4 months, whichever occurs first after the effective date of this AD: Do a low frequency eddy current (LFEC) inspection or a high frequency eddy current (HFEC) inspection for cracking of the pocket radii located between fuselage frames 35 and 40, above stringer 6 on both the left- and right-hand sides, in accordance with the instructions of Airbus Alert Operators Transmission (AOT) A53N009-14, dated December 17, 2014. Repeat the inspection, thereafter, at intervals not to exceed the times specified in paragraphs (g)(1)(i) and (g)(1)(ii) of this AD.
(i) For the LFEC inspection performed on the outside: Repeat the inspection at intervals not to exceed 1,000 flight cycles.
(ii) For the HFEC inspection performed on the inside: Repeat the inspection at intervals not to exceed 2,000 flight cycles.
If, during any inspection required by paragraph (g) of this AD, any crack is found, before further flight, accomplish the repair in accordance with the instructions of Airbus AOT A53N009-14, dated December 17, 2014; except if the crack is beyond the structural repair manual limits as specified in Airbus AOT A53N009-14, dated December 17, 2014, before further flight, repair using a method approved by the Manager, International Branch, ANM-116, Transport Airplane Directorate, FAA; or the European Aviation Safety Agency (EASA); or Airbus's EASA Design Organization Approval (DOA).
Repair of an airplane as required by paragraph (h) of this AD terminates the repetitive inspections required by paragraph (g) of this AD for the repaired area only.
The following provisions also apply to this AD:
(1)
(2)
(1) Refer to Mandatory Continuing Airworthiness Information (MCAI) EASA Airworthiness Directive 2014-0278, dated December 19, 2014, for related information. This MCAI may be found in the AD docket on the Internet at
(2) For service information identified in this AD, contact Airbus, Airworthiness Office—EIAS, 1 Rond Point Maurice Bellonte, 31707 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).
This action proposes to establish Class E surface area airspace at Pearson Field, Vancouver, WA, to accommodate existing Standard Instrument Approach Procedures (SIAPs) at the airport. The FAA is taking this action to enhance the safety and
Comments must be received on or before October 13, 2015.
Send comments on this proposal to the U.S. Department of Transportation, Docket Operations, M-30, West Building Ground Floor, Room W12-140, 1200 New Jersey Avenue SE., Washington, DC 20590; telephone (202) 366-9826. You must identify FAA Docket No. FAA-2015-3322; Airspace Docket No. 15-ANM-16, at the beginning of your comments. You may also submit comments through the Internet at
FAA Order 7400.9Y, Airspace Designations and Reporting Points, and subsequent amendments can be viewed online at
FAA Order 7400.9, Airspace Designations and Reporting Points, is published yearly and effective on September 15.
Steve Haga, Federal Aviation Administration, Operations Support Group, Western Service Center, 1601 Lind Avenue SW, Renton, WA 98057; telephone (425) 203-4563.
The FAA's authority to issue rules regarding aviation safety is found in Title 49 of the United States Code. Subtitle I, Section 106 describes the authority of the FAA Administrator. Subtitle VII, Aviation Programs, describes in more detail the scope of the agency's authority. This rulemaking is promulgated under the authority described in Subtitle VII, Part, A, Subpart I, Section 40103. Under that section, the FAA is charged with prescribing regulations to assign the use of airspace necessary to ensure the safety of aircraft and the efficient use of airspace. This regulation is within the scope of that authority as it would establish Class E airspace at Pearson Field, Vancouver, WA.
Interested parties are invited to participate in this proposed rulemaking by submitting such written data, views, or arguments, as they may desire. Comments that provide the factual basis supporting the views and suggestions presented are particularly helpful in developing reasoned regulatory decisions on the proposal. Comments are specifically invited on the overall regulatory, aeronautical, economic, environmental, and energy-related aspects of the proposal. Communications should identify both docket numbers and be submitted in triplicate to the address listed above. Commenters wishing the FAA to acknowledge receipt of their comments on this notice must submit with those comments a self-addressed, stamped postcard on which the following statement is made: “Comments to Docket No. FAA-2015-3322; Airspace Docket No. 15-ANM-16.” The postcard will be date/time stamped and returned to the commenter.
An electronic copy of this document may be downloaded through the Internet at
You may review the public docket containing the proposal, any comments received, and any final disposition in person in the Dockets Office (see the
Persons interested in being placed on a mailing list for future NPRMs should contact the FAA's Office of Rulemaking, (202) 267-9677, for a copy of Advisory Circular No. 11-2A, Notice of Proposed Rulemaking Distribution System, which describes the application procedure.
This document proposes to amend FAA Order 7400.9Y, Airspace Designations and Reporting Points, dated August 6, 2014, and effective September 15, 2014. FAA Order 7400.9Y is publicly available as listed in the
The FAA is proposing an amendment to Title 14 Code of Federal Regulations (14 CFR) Part 71 by establishing Class E surface area airspace at Pearson Field, Vancouver, WA. A review of the airspace revealed establishment necessary due to current standard instrument approach procedures not contained within controlled airspace.
Class E surface area airspace would be established to an area 4.9 miles west, 4 miles east, 2.9 miles north, and 1.8 miles south of Pearson Field.
Class E airspace designations are published in paragraph 6002 of FAA Order 7400.9Y, dated August 6, 2014, and effective September 15, 2014, which is incorporated by reference in 14 CFR 71.1. The Class E airspace designations listed in this document will be published subsequently in the Order.
The FAA has determined this proposed regulation only involves an established body of technical regulations for which frequent and routine amendments are necessary to keep them operationally current. Therefore, this proposed regulation; (1) Is not a “significant regulatory action” under Executive Order 12866; (2) is not a “significant rule” under DOT Regulatory Policies and Procedures (44 FR 11034; February 26, 1979); and (3) does not warrant preparation of a regulatory evaluation as the anticipated impact is so minimal. Since this is a routine matter that will only affect air traffic procedures and air navigation, it is certified this proposed rule, when promulgated, would not have a significant economic impact on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
This proposal will be subject to an environmental analysis in accordance with FAA Order 1050.1E, “Environmental Impacts: Policies and Procedures” prior to any FAA final regulatory action.
Airspace, Incorporation by reference, Navigation (air).
Accordingly, pursuant to the authority delegated to me, the Federal Aviation Administration proposes to amend 14 CFR part 71 as follows:
49 U.S.C. 106(f), 106(g); 40103, 40113, 40120; E.O. 10854, 24 FR 9565, 3 CFR, 1959-1963 Comp., p. 389.
Federal Aviation Administration (FAA), DOT.
Notice of proposed rulemaking (NPRM).
This action proposes to establish Class E en route domestic airspace in the International Falls, MN area, to facilitate vectoring of Instrument Flight Rules (IFR) aircraft under control of Minneapolis Air Route Traffic Control Center (ARTCC). The FAA is proposing this action to enhance the safety and efficiency of aircraft operations within the National Airspace System (NAS).
Comments must be received on or before October 13, 2015.
Send comments on this proposal to the U.S. Department of Transportation, Docket Operations, 1200 New Jersey Avenue SE., West Building Ground Floor, Room W12-140, Washington, DC 20590-0001. You must identify the docket number FAA-2015-3084/Airspace Docket No. 15-AGL-13, at the beginning of your comments. You may also submit comments through the Internet at
FAA Order 7400.9Y, Airspace Designations and Reporting Points, and subsequent amendments can be viewed online at
FAA Order 7400.9, Airspace Designations and Reporting Points, is published yearly and effective on September 15. For further information, you can contact the Airspace Policy and Regulations Group, Federal Aviation Administration, 800 Independence Avenue SW., Washington, DC 20591; telephone: 202-267-8783.
Raul Garza, Jr., Central Service Center, Operations Support Group, Federal Aviation Administration, Southwest Region, 2601 Meacham Blvd., Fort Worth, TX 76137; telephone: 817-222-4075.
The FAA's authority to issue rules regarding aviation safety is found in Title 49 of the United States Code. Subtitle I, Section 106 describes the authority of the FAA Administrator. Subtitle VII, Aviation Programs, describes in more detail the scope of the agency's authority. This rulemaking is promulgated under the authority described in Subtitle VII, Part, A, Subpart I, Section 40103. Under that section, the FAA is charged with prescribing regulations to assign the use of airspace necessary to ensure the safety of aircraft and the efficient use of airspace. This regulation is within the scope of that authority as it would establish Class E airspace in the International Falls, MN, area.
Interested parties are invited to participate in this proposed rulemaking by submitting such written data, views, or arguments, as they may desire. Comments that provide the factual basis supporting the views and suggestions presented are particularly helpful in developing reasoned regulatory decisions on the proposal. Comments are specifically invited on the overall regulatory, aeronautical, economic, environmental, and energy-related aspects of the proposal. Communications should identify both docket numbers and be submitted in triplicate to the address listed above. Commenters wishing the FAA to acknowledge receipt of their comments on this notice must submit with those comments a self-addressed, stamped postcard on which the following statement is made: “Comments to Docket No. FAA-2015-3084/Airspace Docket No. 15-AGL-13.” The postcard will be date/time stamped and returned to the commenter.
An electronic copy of this document may be downloaded through the Internet at
You may review the public docket containing the proposal, any comments received and any final disposition in person in the Dockets Office (see
Persons interested in being placed on a mailing list for future NPRMs should contact the FAA's Office of Rulemaking (202) 267-9677, to request a copy of
This document proposes to amend FAA Order 7400.9Y, Airspace Designations and Reporting Points, dated August 6, 2014, and effective September 15, 2014. FAA Order 7400.9Y is publicly available as listed in the
This action proposes to amend Title 14, Code of Federal Regulations (14 CFR), Part 71 by establishing Class E en route domestic airspace extending upward from 1,200 feet above the surface in the International Falls, MN area. This action would contain aircraft while in IFR conditions under control of Minneapolis ARTCC by safely vectoring aircraft from en route airspace to terminal areas.
Class E airspace areas are published in Paragraph 6006 of FAA Order 7400.9Y, August 6, 2014, and effective September 15, 2014, which is incorporated by reference in 14 CFR 71.1. The Class E airspace designation listed in this document would be published subsequently in the Order.
The FAA has determined that this proposed regulation only involves an established body of technical regulations for which frequent and routine amendments are necessary to keep them operationally current. It, therefore, (1) is not a “significant regulatory action” under Executive Order 12866; (2) is not a “significant rule” under DOT Regulatory Policies and Procedures (44 FR 11034; February 26, 1979); and (3) does not warrant preparation of a Regulatory Evaluation as the anticipated impact is so minimal. Since this is a routine matter that will only affect air traffic procedures and air navigation, it is certified that this rule, when promulgated, will not have a significant economic impact on a substantial number of small entities under the criteria of the Regulatory Flexibility Act.
This proposal will be subject to an environmental analysis in accordance with FAA Order 1050.1E, “Environmental Impacts: Policies and Procedures” prior to any FAA final regulatory action.
Airspace, Incorporation by reference, Navigation (air).
In consideration of the foregoing, the Federal Aviation Administration proposes to amend 14 CFR part 71 as follows:
49 U.S.C. 106(f), 106(g); 40103, 40113, 40120; E.O. 10854, 24 FR 9565, 3 CFR, 1959-1963 Comp., p. 389.
That airspace extending upward from 1,200 feet above the surface within an area bounded by lat. 49°00′00″ N., long. 095°00′00″ W.; to lat. 49°00′00″ N., long. 093°30′00″ W.; to lat. 48°06′30″ N., long. 090°06′00″ W.; to lat. 47°53′00″ N., long. 090°55′00″ W.; to lat. 48°34′00″ N., long. 094°00′00″ W.; to lat. 48°40′00″ N., long. 095°00′00″ W., thence to the point of beginning, excluding that airspace within Federal airways.
Office of National Marine Sanctuaries (ONMS), National Ocean Service (NOS), National Oceanic and Atmospheric Administration (NOAA), Department of Commerce (DOC).
Initiation of review of management plan and regulations; intent to conduct scoping and prepare environmental impact statement.
Monterey Bay National Marine Sanctuary (MBNMS or sanctuary) was designated in September 1992. It spans 4,601 square nautical miles (6.094 square miles) of marine waters off the central California coast, encompassing several large, nearshore submarine canyons, an offshore seamount and numerous marine habitats representative of the central California coastal and marine ecosystem. The present management plan was written and published in 2008 along with a final environmental impact statement in accordance with the National Environmental Policy Act (NEPA). In accordance with Section 304(e) of the National Marine Sanctuaries Act, as amended, (NMSA), the Office of National Marine Sanctuaries (ONMS) of the National Oceanic and Atmospheric Administration (NOAA) is initiating a review of the MBNMS management plan, to evaluate substantive progress toward implementing the goals for the sanctuary, and to make revisions to the plan and regulations as necessary to fulfill the purposes and policies of the NMSA. NOAA anticipates regulatory and management plan changes will require preparation of an environmental analysis under the National Environmental Policy Act (NEPA). NOAA will conduct public scoping meetings to gather information and other comments from individuals, organizations, tribes, and government agencies on the scope, types and significance of issues related to the MBNMS management plan and regulations and the proper scope of environmental review for the project. The scoping meetings are scheduled as detailed below.
Written comments should be received on or before October 30, 2015.
Scoping meetings will be held on:
(1) September 10, 6-8 p.m., Monterey Conference Center, Monterey, CA.
(2) September 23, 6-8 p.m., Louden Nelson Center, Santa Cruz, CA.
(3) October 23, 6-8 p.m., Veteran's Memorial Hall, Cambria, CA.
You may submit comments on this document, identified by NOAA-NOS-2015-0999, by any of the following methods:
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Dawn Hayes, 831.647.4256,
Reviewing the MBNMS management plan may result in proposed changes to existing plans and policies to address contemporary issues and challenges, and better protect and manage the sanctuary's resources and qualities. The review process is composed of four major stages: (1) Information collection and characterization; (2) preparation and release of a draft management plan and environmental impact statement, and any proposed amendments to the regulations; (3) public review and comment; (4) preparation and release of a final management plan and environmental document, and any final amendments to the regulations. NOAA will also address other statutory and regulatory requirements that may be required pursuant to the Endangered Species Act, Marine Mammal Protection Act, Essential Fish Habitat provisions of the Magnuson-Stevens Act, and the National Historic Preservation Act.
NOAA has prepared a preliminary list of priority topics to consider during the MBNMS management plan review process. We are interested in public comment on these topics, as well as any other topics of interest to the public or other agencies in the context of the MBNMS management plan review. This list does not preclude or in any way limit the consideration of additional topics raised through public comment, government-to-government and interagency consultations, and discussions with partner agencies.
There is a continuing need for characterization, research and monitoring to understand baseline conditions of marine resources within the sanctuary, ecosystem functions, and status and trends of biological and socioeconomic resources. NOAA relies on the continued support of multiple partners and volunteers, and strives to address critical resource protection through collaborative multi-stakeholder management efforts. In addition to updating existing action plans in the management plan, NOAA is considering adding strategies and activities to address the following issues:
Climate Change—Climate change is widely acknowledged, yet there is considerable uncertainty about current and future consequences at local, ecosystem and oceanic scales. Increased coordination and cooperation among science and resource management agencies are required to improve planning, monitoring and adaptive management to address this phenomenon as it pertains to the protection of MBNMS resources.
Wildlife Disturbance—MBNMS is an active area with abundant human use, offering some of the most significant marine wildlife viewing in the world. NOAA is concerned about a variety of human activities that have the ability to disturb marine wildlife. The harassment of wildlife, in particular marine mammals, has increased in recent years due to increased numbers (and proximity) of certain whale species and humans involved in on-the-water activities. Impacts to the MBNMS soundscape are also a concern, as the cumulative effects of underwater noise generated by a variety of human activities have grown over the past half century. Expanded use of unmanned aircraft systems over the sanctuary may also require additional analysis to determine the degree to which these aircraft may, or may not, be causing harm to wildlife.
Water Quality Protection—Water quality is key to ensuring protection for all sanctuary resources. Given the level of coastal development along MBNMS's extensive coastline, runoff of contaminants such as sediments, nutrients, fecal bacteria, pesticides, oil, grease, metals, and detergents from the approximately 7,000 square miles of coastal watershed areas makes the sanctuary vulnerable to coastal water pollution problems. Although MBNMS has an award-winning water quality protection program, NOAA believes that more focused attention on specific water quality issues is needed, as well as a coordinated regional monitoring program to provide meaningful information on conditions, trends, and contaminant loads.
Marine Debris—Coastal marine debris is a persistent and poorly diagnosed problem within the sanctuary that negatively impacts natural and socioeconomic resources and qualities, including marine mammals, turtles and seabirds. NOAA is seeking input on innovative source controls and cleanups could help minimize impacts to sanctuary waters and habitats.
NOAA is considering several modifications to MBNMS regulations and definitions to facilitate resource protection, clarify legal intent, and enhance public understanding. These include: Clarifying the extent of the shoreward sanctuary boundary line and the means by which some of the zones within MBNMS are delineated; clarifying the intent of the prohibition on the take of historical resources; and prohibiting tampering with MBNMS signage and buoys. Other regulatory changes may be considered based on public scoping comments and staff work to adjust various action plans within the management plan.
Other potential regulatory modifications on which NOAA is seeking public input include:
(1) Reducing the required High Surf Warning (HSW) condition for Motorized Personal Watercraft operations at Mavericks to a High Surf Advisory (HSA) condition.
(2) Minimizing disturbance from low overflights in the area of the Common Murre colony at Devil's Slide, a restoration site just beyond the MBNMS boundary line at Point San Pedro (San Mateo County).
(3) Designating of specific zones where fireworks may be permitted within MBNMS.
(4) Updating regulations to clarify the extent of the shoreward sanctuary boundary line.
(5) Ensuring that salvers operating within MBNMS meet minimum industry standards for safety, liability, capacity, and environmentally sensitive salvage techniques during both emergency and non-emergency operations.
(6) Clarifying the definition of “cruise ship” to include not only ships with berths for hire as is currently defined, but also ships with condominiums under private ownership.
(7) Clarifying the intent and applicability of the existing prohibition on deserting a vessel in MBNMS.
Enhancing the public's awareness and appreciation of sanctuary resources is a cornerstone of MBNMS's mission. Recent initiatives, such as visitor centers, video media production, and partnering with recreation and tourism industry offer opportunities for NOAA and other entities to expand educational and outreach contributions and reach larger audiences. NOAA is seeking the public's view on developing and enhancing programs designed to enhance public awareness, including opportunities to participate in environmental research and monitoring.
To inform the MBNMS management plan review, NOAA is updating the Monterey Bay National Marine Sanctuary Condition Report, which was first published in 2009. The 2009 report provided a summary of resources in MBNMS, pressures on those resources, current conditions and recent trends within the Sanctuary, and management responses to mitigate negative impacts. The 2015 Condition Report will update current conditions and recent changes for water quality, habitat, living resources and maritime archaeological resources in the sanctuary. It will also include an assessment of the Davidson Seamount Management Zone which NOAA added to MBNMS in 2009.
A summary of the 2015 Condition Report will be available to the general public during the public scoping period and on the Internet at:
NOAA is interested in hearing the public's view on:
• The potential impacts of the proposed actions discussed above and ways to mitigate these impacts.
• The topics discussed above for the next five to ten years and whether these are the right topics, the priority topics, or if there are additional topics NOAA should consider.
• The effectiveness of the existing management plan in meeting both the mandates of the NMSA and MBNMS goals and objectives.
• The public's view on the effectiveness of the MBNMS programs, including programs focused on: Resource protection; research and monitoring; education; volunteer; and outreach.
• NOAA's implementation of MBNMS regulations and permits.
• Adequacy of existing boundaries to protect sanctuary resources.
• Assessment of the existing operational and administrative framework (staffing, offices, vessels, etc.).
This document also advises the public that NOAA will coordinate its consultation responsibilities under section 7 of the Endangered Species Act (ESA), Essential Fish Habitat (EFH) under the Magnuson Stevens Fishery Conservation and Management Act (MSA), section 106 of the National Historic Preservation Act (NHPA, 16 U.S.C. 470), and Federal Consistency review under the Coastal Zone Management Act (CZMA), along with its ongoing NEPA process including the use of NEPA documents and public and stakeholder meetings to also meet the requirements of other federal laws.
In fulfilling its responsibility under the NHPA and NEPA, NOAA intends to identify consulting parties; identify historic properties and assess the effects of the undertaking on such properties; initiate formal consultation with the State Historic Preservation Officer, the Advisory Council of Historic Preservation, and other consulting parties; involve the public in accordance with NOAA's NEPA procedures, and develop in consultation with identified consulting parties alternatives and proposed measures that might avoid, minimize or mitigate any adverse effects on historic properties and describe them in any environmental assessment or draft environmental impact statement.
16 U.S.C. 1431
Internal Revenue Service (IRS), Treasury.
Notice of proposed rulemaking.
This document contains proposed amendments to the regulations for determining whether an individual is a bona fide resident of a U.S. territory. These proposed amendments affect individuals establishing bona fide residency in a U.S. territory by allowing additional days of constructive presence in a U.S. territory.
Written or electronic comments and requests for a public hearing must be received by November 25, 2015.
Send submissions to: CC:PA:LPD:PR (REG-109813-11), room 5203, Internal Revenue Service, P.O. Box 7604, Ben Franklin Station, Washington, DC 20044. Submissions may be hand-delivered Monday through Friday between the hours of 8 a.m. and 4 p.m. to CC:PA:LPD:PR (REG-109813-11), Courier's Desk, Internal Revenue Service, 1111 Constitution Avenue NW., Washington, DC, or sent electronically, via the Federal eRulemaking Portal at
Concerning the proposed regulations, Stephen Huggs, (202) 317-6941; concerning submission of comments and/or requests for a hearing, Oluwafunmilayo (Funmi) Taylor, (202) 317-6901 (not toll-free numbers).
This document contains proposed amendments to the Income Tax Regulations (26 CFR part 1) under section 937 of the Internal Revenue Code (Code). Section 937 was added to the Code by the American Jobs Creation Act of 2004 (Public Law 108-357, 118
On April 11, 2005, the
Section 937(a) provides that an individual is a bona fide resident of a U.S. territory if the individual meets a presence test, a tax home test, and a closer connection test. In order to satisfy the presence test, an individual must be present in the U.S. territory for at least 183 days during the taxable year (183-day rule), unless otherwise provided in regulations.
Section 1.937-1 provides several alternatives to the 183-day rule. An individual who does not satisfy the 183-day rule nevertheless meets the presence test if the individual satisfies one of four alternative tests: (1) The individual is present in the relevant U.S. territory for at least 549 days during the three-year period consisting of the current taxable year and the two immediately preceding taxable years, provided the individual is present in the U.S. territory for at least 60 days during each taxable year of the period; (2) the individual is present no more than 90 days in the United States during the taxable year; (3) the individual has no more than $3,000 of earned income from U.S. sources and is present for more days in the U.S. territory than in the United States during the taxable year; or (4) the individual has no significant connection to the United States during the taxable year. The term “significant connection” is generally defined as a permanent home, voter registration, spouse, or minor child in the United States. See § 1.937-1(c)(5). Section 1.937-1 also provides that certain days count as days of presence in the relevant U.S. territory for purposes of the presence test, even if the individual is not physically present in the U.S. territory (constructive presence).
Following the original issuance of § 1.937-1, the Department of the Treasury (Treasury Department) and the Internal Revenue Service (IRS) received comments requesting that the presence test be revisited to make it more flexible. These comments included a proposal to allow days of constructive presence for business or personal travel outside of the relevant U.S. territory. The Treasury Department and the IRS have concluded that it would be appropriate to allow additional days of constructive presence subject to certain limitations. Accordingly, these proposed regulations provide an additional rule for calculating days of presence in the relevant U.S. territory for purposes of the presence test in § 1.937-1(c)(1).
Under the proposed amendment, an individual would be considered to be present in the relevant U.S. territory for up to 30 days during which the individual is outside of both the United States and the relevant U.S. territory. The proposed amendment would not apply, however, if the number of days that the individual is considered to be present in the United States during the taxable year equals or exceeds the number of days that the individual is considered to be present in the relevant U.S. territory during the taxable year, determined without taking into account any days for which the individual would be treated as present in the U.S. territory under this proposed amendment. Furthermore, the 30-day constructive presence rule would not apply for purposes of calculating the minimum 60 days of presence in the relevant U.S. territory that is required for the 549-day test under § 1.937-1(c)(1)(ii). Therefore, an individual invoking § 1.937-1(c)(1)(ii) must otherwise be considered to have been present at least 60 days in the relevant U.S. territory in each of the three years in order to benefit from the 30-day constructive presence rule.
These amendments to the regulations are proposed to apply to taxable years beginning after the date these regulations are published as final regulations in the
Until these regulations are published as final regulations in the
Certain IRS regulations, including this one, are exempt from the requirements of Executive Order 12866, as supplemented and reaffirmed by Executive Order 13563. Therefore, a regulatory impact assessment is not required. It has also been determined that section 553(b) of the Administrative Procedure Act (5 U.S.C. chapter 5) does not apply to these regulations, and because the regulations do not impose a collection of information on small entities, the Regulatory Flexibility Act (5 U.S.C. chapter 6) does not apply. Pursuant to section 7805(f) of the Code, this regulation has been submitted to the Chief Counsel for Advocacy of the Small Business Administration for comment on its impact on small business.
Before these proposed regulations are adopted as final regulations, consideration will be given to any comments that are submitted timely to the IRS as prescribed in this preamble under the
The principal author of these proposed regulations is Cleve Lisecki, formerly of the Office of Associate Chief Counsel (International). However, other personnel from the Treasury Department and the IRS participated in their development.
Income taxes, Reporting and recordkeeping requirements.
Accordingly, 26 CFR part 1 is proposed to be amended as follows:
26 U.S.C. 7805 * * *
Section 1.937-1 also issued under 26 U.S.C. 937(a). * * *
The revisions and additions read as follows:
(c) * * *
(3) * * *
(i) * * *
(B) Any day that an individual is outside of the relevant possession to receive, or to accompany on a full-time basis a parent, spouse, or child (as defined in section 152(f)(1)) who is receiving, qualifying medical treatment as defined in paragraph (c)(4) of this section;
(C) * * *
(
(
(D) Any day not described in paragraph (c)(3)(i)(B) or (C) of this section that an individual is outside of the United States and the relevant possession, except that an individual will not be considered present in the relevant possession under this paragraph (c)(3)(i)(D) for more than 30 days during the taxable year, and this paragraph (c)(3)(i)(D) does not apply for purposes of calculating the required minimum 60 days of presence in the relevant possession under paragraph (c)(1)(ii) of this section. Furthermore, this paragraph (c)(3)(i)(D) applies only if the number of days that the individual is considered to be present in the relevant possession during the taxable year, determined without regard to this paragraph (c)(3)(i)(D), exceeds the number of days that the individual is considered to be present in the United States during the taxable year.
(g) * * *
(i) * * * Notwithstanding the foregoing, paragraph (c)(3)(i)(D) and
Internal Revenue Service (IRS), Treasury.
Notice of proposed rulemaking, notice of proposed rulemaking by cross reference to temporary regulations and notice of public hearing.
This document contains proposed regulations involving the domestic production activities deduction under section 199 of the Internal Revenue Code (Code). The proposed regulations provide guidance to taxpayers on the amendments made to section 199 by the Energy Improvement and Extension Act of 2008 and the Tax Extenders and Alternative Minimum Tax Relief Act of 2008, involving oil related qualified production activities income and qualified films, and the American Taxpayer Relief Act of 2012, involving activities in Puerto Rico. The proposed regulations also provide guidance on: Determining domestic production gross receipts; the terms manufactured, produced, grown, or extracted; contract manufacturing; hedging transactions; construction activities; allocating cost of goods sold; and agricultural and horticultural cooperatives. In the Rules and Regulations of this issue of the
Written or electronic comments must be received by November 25, 2015. Outlines of topics to be discussed at the public hearing scheduled for December 16, 2015, at 10:00 a.m., must be received by November 25, 2015.
Send submissions to: CC:PA:LPD:PR (REG-136459-09), Room 5203, Internal Revenue Service, P.O. Box 7604, Ben Franklin Station, Washington, DC 20044. Submissions may be hand-delivered Monday through Friday between the hours of 8 a.m. and 4 p.m. to CC:PA:LPD:PR (REG-136459-09), Courier's Desk, Internal Revenue Service, 1111 Constitution Avenue NW., Washington, DC, or sent electronically, via the Federal eRulemaking Portal at
Concerning §§ 1.199-1(f), 1.199-2(c), 1.199-2(e), 1.199-2(f), 1.199-3(b), 1.199-3(e), 1.199-3(h), 1.199-3(k), 1.199-3(m), 1.199-6(m), and 1.199-8(i) of the proposed regulations, James Holmes, (202) 317-4137; concerning § 1.199-4(b) of the proposed regulations, Natasha Mulleneaux (202) 317-7007; concerning submissions of comments, the hearing, or to be placed on the building access list to attend the hearing, Regina Johnson, at (202) 317-6901 (not toll-free numbers).
This document contains proposed amendments to §§ 1.199-0, 1.199-1, 1.199-2, 1.199-3, 1.199-4(b), 1.199-6, and 1.199-8(i) of the Income Tax Regulations (26 CFR part 1). Section 1.199-1 relates to income that is attributable to domestic production activities. Section 1.199-2 relates to W-2 wages as defined in section 199(b). Section 1.199-3 relates to determining domestic production gross receipts (DPGR). Section 1.199-4(b) describes the costs of goods sold allocable to DPGR. Section 1.199-6 applies to agricultural and horticultural cooperatives. Section 1.199-8(i) provides the effective/applicability dates.
Section 199 was added to the Code by section 102 of the American Jobs Creation Act of 2004 (Pub. L. 108-357, 118 Stat. 1418 (2004)), and amended by section 403(a) of the Gulf Opportunity Zone Act of 2005 (Pub. L. 109-135, 119 Stat. 25 (2005)), section 514 of the Tax Increase Prevention and Reconciliation Act of 2005 (Pub. L. 109-222, 120 Stat. 345 (2005)), section 401 of the Tax Relief and Health Care Act of 2006 (Pub. L. 109-432, 120 Stat. 2922 (2006)), section 401(a), Division B of the Energy Improvement and Extension Act of 2008 (Pub. L. 110-343, 122 Stat. 3765 (2008)) (Energy Extension Act of 2008), sections 312(a) and 502(c), Division C of the Tax Extenders and Alternative Minimum Tax Relief Act of 2008 (Pub. L. 110-343, 122 Stat. 3765 (2008)) (Tax Extenders Act of 2008), section 746(a) of the Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010 (Pub. L. 111-312, 124 Stat. 3296 (2010)), section 318 of the American Taxpayer Relief Act of 2012 (Pub. L. 112-240, 126 Stat. 2313 (2013)), and sections 130 and 219(b) of the Tax Increase Prevention Act of 2014 (Pub. L. 113-295, 128 Stat. 4010 (2014)).
Section 199(a)(1) allows a deduction equal to nine percent (three percent in the case of taxable years beginning in 2005 or 2006, and six percent in the case of taxable years beginning in 2007, 2008, or 2009) of the lesser of: (A) The qualified production activities income (QPAI) of the taxpayer for the taxable year, or (B) taxable income (determined without regard to section 199) for the taxable year (or, in the case of an individual, adjusted gross income).
Section 199(b)(1) provides that the amount of the deduction allowable under section 199(a) for any taxable year shall not exceed 50 percent of the W-2 wages of the taxpayer for the taxable year. Section 199(b)(2)(A) generally defines
Section 199(c)(1) defines QPAI for any taxable year as an amount equal to the excess (if any) of: (A) The taxpayer's DPGR for such taxable year, over (B) the sum of: (i) The cost of goods sold (CGS) that are allocable to such receipts; and (ii) other expenses, losses, or deductions (other than the deduction under section 199) that are properly allocable to such receipts.
Section 199(c)(4)(A)(i) provides that the term DPGR means the taxpayer's gross receipts that are derived from any lease, rental, license, sale, exchange, or other disposition of: (I) Qualifying
Section 199(d)(10), as renumbered by section 401(a), Division B of the Energy Extension Act of 2008, authorizes the Secretary to prescribe such regulations as are necessary to carry out the purposes of section 199, including regulations that prevent more than one taxpayer from being allowed a deduction under section 199 with respect to any activity described in section 199(c)(4)(A)(i).
Temporary regulations in the Rules and Regulations section of this issue of the
Section 401(a), Division B of the Energy Extension Act of 2008 added new section 199(d)(9), which applies to taxable years beginning after December 31, 2008. Section 199(d)(9) reduces the otherwise allowable section 199 deduction when a taxpayer has oil related qualified production activities income (oil related QPAI), and defines oil related QPAI. Section 199(d)(9)(A) provides that if a taxpayer has oil related QPAI for any taxable year beginning after 2009, the amount otherwise allowable as a deduction under section 199(a) must be reduced by three percent of the least of: (i) The oil related QPAI of the taxpayer for the taxable year, (ii) the QPAI of the taxpayer for the taxable year, or (iii) taxable income (determined without regard to section 199).
Section 1.199-1(f) of the proposed regulations provides guidance on oil related QPAI. In defining oil related QPAI, the Treasury Department and the IRS considered the relationship between QPAI and oil related QPAI. Section 199(c)(1) defines QPAI as the amount equal to the excess (if any) of the taxpayer's DPGR for the taxable year over the sum of CGS allocable to such receipts and other costs, expenses, losses, and deductions allocable to such receipts. So, for example, if gross receipts are not included within DPGR, those gross receipts are not included when calculating QPAI. Section 199(d)(9)(B) defines oil related QPAI as QPAI attributable to the production, refining, processing, transportation, or distribution of oil, gas, or any primary product thereof. In general, gross receipts from the transportation and distribution of QPP are not includable in DPGR because those activities are not considered part of the MPGE of QPP. See § 1.199-3(e)(1), which defines MPGE. Section 199(c)(4)(B)(ii) specifically excludes gross receipts attributable to the transmission or distribution of natural gas from the definition of DPGR.
Based on these considerations, the proposed regulations define
The proposed regulations define
Section 1.199-1(f)(2) of the proposed regulations provides guidance on how a taxpayer should allocate and apportion costs under the section 861 method, the simplified deduction method, and the small business simplified overall method when determining oil related QPAI. The proposed regulations require taxpayers to use the same cost allocation method to allocate and apportion costs to oil related DPGR as the taxpayer uses to allocate and apportion costs to DPGR.
Section 502(c), Division C of the Tax Extenders Act of 2008 amended the rules relating to qualified films. Section 502(c)(1) added section 199(b)(2)(D) to broaden the definition of the term
Section 502(c)(2), Division C of the Tax Extenders Act of 2008 amended the definition of qualified film in section 199(c)(6) to mean any property described in section 168(f)(3) if not less than 50 percent of the total compensation relating to production of the property is compensation for services performed in the United States by actors, production personnel, directors, and producers. The term does not include property with respect to which records are required to be maintained under 18 U.S.C. 2257 (generally, films, videotapes, or other matter that depict actual sexually explicit conduct and are produced in whole or in part with materials that have been mailed or shipped in interstate or foreign commerce, or are shipped or transported or are intended for shipment or transportation in interstate or foreign commerce). Section 502(c)(2), Division C of the Tax Extenders Act of 2008 also amended the definition of a qualified film under section 199(c)(6) to include any copyrights, trademarks, or other intangibles with respect to such film. The method and means of distributing a qualified film does not affect the availability of the deduction.
Section 502(c)(3), Division C of the Tax Extenders Act of 2008 added an attribution rule for a qualified film for taxpayers who are partnerships or S
The amendments made by section 502(c), Division C of the Tax Extenders Act of 2008 apply to taxable years beginning after December 31, 2007.
Section 1.199-2(e)(1) of the proposed regulations modifies the definition of W-2 wages to include compensation for services (as defined in § 1.199-3(k)(4)) performed in the United States by actors, production personnel, directors, and producers (as defined in § 1.199-3(k)(1)).
To address the amendments to the definition of qualified film in section 199(c)(6) for taxable years beginning after 2007, the proposed regulations amend the definition of qualified film in § 1.199-3(k)(1) to include copyrights, trademarks, or other intangibles with respect to such film. The proposed regulations define other intangibles with a non-exclusive list of intangibles that fall within the definition.
Section 1.199-3(k)(10) provides a special rule for disposition of promotional films to address concerns of the Treasury Department and the IRS that the inclusion of intangibles in the definition of qualified film could be interpreted too broadly. This rule clarifies that, when a taxpayer produces a qualified film that is promoting a product or service, the gross receipts a taxpayer later derives from the disposition of the product or service promoted in the qualified film are derived from the disposition of the product or service and not from a disposition of the qualified film (including any intangible with respect to such qualified film). The rule is intended to prevent taxpayers from claiming that gross receipts are derived from the disposition of a qualified film (rather than the product or service itself) when a taxpayer sells a product or service with a logo, trademark, or other intangible that appears in a promotional film produced by the taxpayer. The Treasury Department and the IRS recognize that a taxpayer can, in certain cases, derive gross receipts from a disposition of a promotional film or the intangibles in a promotional film. The proposed regulations add
The proposed regulations add four examples in redesignated § 1.199-3(k)(11), formerly § 1.199-3(k)(10), to illustrate application of the amended definition of qualified film that includes copyrights, trademarks, or other intangibles.
The proposed regulations remove the last sentence of § 1.199-3(k)(3)(ii) (which states that gross receipts derived from a license of the right to use or exploit film characters are not gross receipts derived from a qualified film) because gross receipts derived from a license of the right to use or exploit film characters are now considered gross receipts derived from a qualified film.
Section 1.199-3(k)(2)(ii), which allows a taxpayer to treat certain tangible personal property as a qualified film (for example, a DVD), is amended to exclude film intangibles because tangible personal property affixed with a film intangible (such as a trademark) should not be treated as a qualified film. For example, the total revenue from the sale of an imported t-shirt affixed with a film intangible should not be treated as gross receipts derived from the sale of a qualified film. The portion of the gross receipts attributable to the qualified film intangible separate from receipts attributable to the t-shirt may qualify as DPGR, however. The proposed regulations also add
Section 1.199-3(k)(3)(i) and (k)(3)(ii) of the proposed regulations address the amendment to section 199(c)(6) (effective for taxable years beginning after 2007) that provides the methods and means of distributing a qualified film will not affect the availability of the deduction under section 199. The exception that describes the receipts from showing a qualified film in a movie theater or by broadcast on a television station as not derived from a qualified film is removed from § 1.199-3(k)(3)(ii) because, if a taxpayer produces a qualified film, then the receipts the taxpayer derives from these showings qualify as DPGR in taxable years beginning after 2007. In addition,
The proposed regulations also add a sentence to § 1.199-3(k)(6) to clarify that production activities do not include activities related to the transmission or distribution of films. The Treasury Department and the IRS are aware that some taxpayers have taken the inappropriate position that these activities are part of the production of a film. The Treasury Department and the IRS consider film production as distinct from the transmission and distribution of films. This clarification is also consistent with the amendment to the definition of qualified film, which provides that the methods and means of distribution do not affect the availability of the deduction under section 199.
Section 1.199-3(i)(9) of the proposed regulations describes the application of section 199(d)(1)(A)(iv) to partners and partnerships and shareholders and S corporations for taxable years beginning after 2007. The Treasury Department and the IRS have determined that for a partnership to apply the provisions of section 199(d)(1)(A)(iv) to treat itself as having engaged directly in a film produced by a partner, the partnership must treat itself as a partnership for all purposes of the Code. Further, a partner of a partnership can apply the provisions of section 199(d)(1)(A)(iv) to treat itself as having engaged directly in a film produced by the partnership only if the partnership treats itself as a partnership for all purposes of the Code. Section 1.199-3(i)(9)(i) describes generally that a partner of a partnership or shareholder of an S corporation who owns (directly or indirectly) at least 20 percent of the capital interests in such partnership or the stock of such S corporation is treated as having engaged directly in any film produced by such partnership or S corporation. Further, such partnership or S corporation is treated as having engaged directly in any film produced by such partner or shareholder.
Section 1.199-3(i)(9)(ii) of the proposed regulations generally prohibits attribution between partners of a partnership or shareholders of an S corporation, partnerships with a partner in common, or S corporations with a shareholder in common. Thus, when a partnership or S corporation is treated as having engaged directly in any film produced by a partner or shareholder, any other partners or shareholders who did not participate directly in the production of the film are treated as not having engaged directly in the production of the film at the partner or shareholder level. Similarly, when a partner or shareholder is treated as having engaged directly in any film produced by a partnership or S corporation, any other partnerships or S corporations in which that partner or shareholder owns an interest (excluding the partnership or S corporation that produced the film) are treated as not having engaged directly in the production of the film at the partnership or S corporation level.
Section 1.199-3(i)(9)(iii) of the proposed regulations describes the attribution period for a partner or partnership or shareholder or S corporation under section 199(d)(1)(A)(iv). A partner or shareholder is treated as having engaged directly in any qualified film produced by the partnership or S corporation, and a partnership or S corporation is treated as having engaged directly in any qualified film produced by the partner or shareholder, regardless of when the qualified film was produced, during the period in which the partner or shareholder owns (directly or indirectly) at least 20 percent of the capital interests in the partnership or the stock of the S corporation. During any period that a partner or shareholder owns less than 20 percent of the capital interests in such partnership or the stock of such S corporation that partner or shareholder is not treated as having engaged directly in the qualified film produced by the partnership or S corporation for purposes of § 1.199-3(i)(9)(iii), and that partnership or S corporation is not treated as having engaged directly in any qualified film produced by the partner or shareholder.
Section 1.199-3(i)(9)(iv) of the proposed regulations provides examples that illustrate section 199(d)(1)(A)(iv).
Existing § 1.199-3(k)(7)(i) provides a safe harbor that treats a film as a qualified film produced by the taxpayer if not less than 50 percent of the total compensation for services paid by the taxpayer is compensation for services performed in the United States and the taxpayer satisfies the safe harbor in § 1.199-3(g)(3) for treating a taxpayer as MPGE QPP in whole or significant part in the United States. The Treasury Department and the IRS are aware that it may be unclear how the safe harbor in § 1.199-3(k)(7)(i) applies to costs of live or delayed television programs that may be expensed (specifically, whether such expensed costs are part of the CGS or unadjusted depreciable basis of the qualified film for purposes of § 1.199-3(g)(3)). Further, it may be unclear whether license fees paid for third-party produced programs are included in direct labor and overhead when applying the safe harbor in § 1.199-3(g)(3). The proposed regulations clarify how a taxpayer producing live or delayed television programs should apply the safe harbor in § 1.199-3(k)(7)(i); in particular, how a taxpayer should calculate its unadjusted depreciable basis under § 1.199-3(g)(3)(ii). Specifically, proposed § 1.199-3(k)(7)(i) requires a taxpayer to include all costs paid or incurred in the production of a live or delayed television program in the taxpayer's unadjusted depreciable basis of such program under § 1.199-3(g)(3)(ii), including the licensing fees paid to a third party under § 1.199-3(g)(3)(ii). The proposed regulations further clarify that license fees for third-party produced programs are not included in the direct labor and overhead to produce the film for purposes of applying § 1.199-3(g)(3).
Section 199(d)(8)(A) provides that in the case of any taxpayer with gross receipts for any taxable year from sources within the Commonwealth of Puerto Rico, if all of such receipts are taxable under section 1 or 11 for such taxable year, then for purposes of determining the DPGR of such taxpayer for such taxable year under section 199(c)(4), the term
Section 1.199-2(f) of the proposed regulations modifies the W-2 wage limitation under section 199(b) to the extent provided by section 199(d)(8). Section 1.199-3(h)(2) of the proposed regulations modifies the term
Section 1.199-3(d)(1) provides that a taxpayer determines, using any reasonable method that is satisfactory to the Secretary based on all of the facts and circumstances, whether gross receipts qualify as DPGR on an item-by-item basis. Section 1.199-3(d)(1)(i) provides that item means the property offered by the taxpayer in the normal course of the taxpayer's business for lease, rental, license, sale, exchange, or other disposition (for purposes of § 1.199-3(d), collectively referred to as disposition) to customers, if the gross receipts from the disposition of such property qualify as DPGR. Section 1.199-3(d)(2)(iii) provides that, in the case of construction activities and services or engineering and architectural services, a taxpayer may use any reasonable method that is satisfactory to the Secretary based on all of the facts and circumstances to determine what construction activities and services or engineering or architectural services constitute an item.
The Treasury Department and the IRS are aware that the item rule in § 1.199-3(d)(2)(iii) has been interpreted to mean that the gross receipts derived from the sale of a multiple-building project may be treated as DPGR when only one building in the project is substantially renovated. The Treasury Department and the IRS have concluded that treating gross receipts from the sale of a multiple-building project as DPGR, and the multiple-building project as one item, is not a reasonable method satisfactory to the Secretary for purposes of § 1.199-3(d)(2)(iii) if a taxpayer did not substantially renovate each building in the multiple-building project. Section 1.199-3(d)(4) of the proposed regulations includes an example (
In addition, the Treasury Department and the IRS are aware that taxpayers may be unsure how to apply the item rule in § 1.199-3(d)(2)(i) when the property offered for disposition to customers includes embedded services
Section 1.199-3(e)(1) provides that the term
Section 1.199-3(e)(2) provides that if a taxpayer packages, repackages, labels, or performs minor assembly of QPP and the taxpayer engages in no other MPGE activities with respect to that QPP, the taxpayer's packaging, repackaging, labeling, or minor assembly does not qualify as MPGE with respect to that QPP. This rule has been the subject of recent litigation. See
Section 1.199-3(f)(1) provides that if one taxpayer performs a qualifying activity under § 1.199-3(e)(1), § 1.199-3(k)(1), or § 1.199-3(l)(1) pursuant to a contract with another party, then only the taxpayer that has the benefits and burdens of ownership of the QPP, qualified film, or utilities under Federal income tax principles during the period in which the qualifying activity occurs is treated as engaging in the qualifying activity.
Taxpayers and the IRS have had difficulty determining which party to a contract manufacturing arrangement has the benefits and burdens of ownership of the property while the qualifying activity occurs. Cases analyzing the benefits and burdens of ownership have considered the following factors relevant: (1) Whether legal title passes; (2) how the parties treat the transaction; (3) whether an equity interest was acquired; (4) whether the contract creates a present obligation on the seller to execute and deliver a deed and a present obligation on the purchaser to make payments; (5) whether the right of possession is vested in the purchaser and which party has control of the property or process; (6) which party pays the property taxes; (7) which party bears the risk of loss or damage to the property; (8) which party receives the profits from the operation and sale of the property; and (9) whether a taxpayer actively and extensively participated in the management and operations of the activity. See
Section 199(d)(10) directs the Treasury Department to provide regulations that prevent more than one taxpayer from being allowed a deduction under section 199 with respect to any qualifying activity (as described in section 199(c)(4)(A)(i)). The Treasury Department and the IRS have interpreted the statute to mean that only one taxpayer may claim the section 199 deduction with respect to the same activity performed with respect to the same property. See § 1.199-3(f)(1).
The Large Business and International (LB&I) Division issued an Industry Director Directive on February 1, 2012 (LB&I Control No. LB&I-4-0112-01) (Directive) addressing the benefits and burdens factors. The Directive provides a three-step analysis of facts and circumstances relating to contract terms, production activities, and economic risks to determine whether a taxpayer has the benefits and burdens of ownership for purposes of § 1.199-3(f)(1). LB&I issued a superseding second directive on July 24, 2013 (LB&I Control No. LB&I-04-0713-006), and a third directive updating the second directive on October 29, 2013 (LB&I Control No. LB&I-04-1013-008). The third directive allows a taxpayer to provide a statement explaining the taxpayer's determination that it had the benefits and burdens of ownership, along with certification statements signed under penalties of perjury by the taxpayer and the counterparty verifying that only the taxpayer is claiming the section 199 deduction.
To provide administrable rules that are consistent with section 199, reduce the burden on taxpayers and the IRS in evaluating factors related to the benefits and burdens of ownership, and prevent more than one taxpayer from being allowed a deduction under section 199 with respect to any qualifying activity, the proposed regulations remove the rule in § 1.199-3(f)(1) that treats a taxpayer in a contract manufacturing arrangement as engaging in the qualifying activity only if the taxpayer has the benefits and burdens of ownership during the period in which the qualifying activity occurs. In place of the benefits and burdens of ownership rule, these proposed regulations provide that if a qualifying activity is performed under a contract, then the party that performs the activity is the taxpayer for purposes of section 199(c)(4)(A)(i). This rule, which applies solely for purposes of section 199, reflects the conclusion that the party actually producing the property should be treated as engaging in the qualifying activity for purposes of section 199, and is therefore consistent with the statute's goal of incentivizing domestic
The Treasury Department and the IRS request comments on whether there are narrow circumstances that could justify an exception to the proposed rule. In particular, the Treasury Department and the IRS request comments on whether there should be a limited exception to the proposed rule for certain fully cost-plus or cost-reimbursable contracts. Under such an exception, the party that is not performing the qualifying activity would be treated as the taxpayer engaged in the qualifying activity if the party performing the qualifying activity is (i) reimbursed for, or provided with, all materials, labor, and overhead costs related to fulfilling the contract, and (ii) provided with an additional payment to allow for a profit. The Treasury Department and the IRS are uncertain regarding the extent to which such fully cost-plus or cost-reimbursable contracts are in fact used in practice. Comments suggesting circumstances that could justify an exception to the proposed rule should address the rationale for the proposed exception, the ability of the IRS to administer the exception, and how the suggested exception will prevent two taxpayers from claiming the deduction for the qualifying activity.
The proposed regulations make several revisions to the hedging rules in § 1.199-3(i)(3). Section 1.199-3(i) of the proposed regulations defines a hedging transaction to include transactions in which the risk being hedged relates to property described in section 1221(a)(1) giving rise to DPGR, whereas the existing regulations require the risk being hedged relate to QPP described in section 1221(a)(1). A taxpayer commented in a letter to the Treasury Department and the IRS that there is no reason to limit the hedging rules to QPP giving rise to DPGR, and the proposed regulations accept the comment.
The other changes to the hedging rules are administrative. Section 1.199-3(i)(3)(ii) of the existing regulations on currency fluctuations was eliminated because the regulations under sections 988(d) and 1221 adequately cover the treatment of currency hedges. Similarly, the rules in § 1.199-3(i)(3)(iii) that address the effect of identification and non-identification were duplicative of the rules in the section 1221 regulations. Accordingly, § 1.199-3(i)(3)(ii) has been revised to cross-reference the appropriate rules in § 1.1221-2(g), and to clarify that the consequence of an abusive identification or non-identification is that deduction or loss, but not income or gain, is taken into account in calculating DPGR.
Section 199(c)(4)(A)(ii) includes in DPGR, in the case of a taxpayer engaged in the active conduct of a construction trade or business, gross receipts derived from construction of real property performed in the United States by the taxpayer in the ordinary course of such trade or business. Under § 1.199-3(m)(2)(i), activities constituting construction include activities performed by a general contractor or activities typically performed by a general contractor, for example, activities relating to management and oversight of the construction process such as approvals, periodic inspection of progress of the construction project, and required job modifications. The Treasury Department and the IRS are aware that some taxpayers have interpreted this language to mean that a taxpayer who only approves or authorizes payments is engaged in activities typically performed by a general contractor under § 1.199-3(m)(2)(i). The Treasury Department and the IRS disagree that a taxpayer who only approves or authorizes payments is engaged in construction for purposes of § 1.199-3(m)(2)(i). Accordingly, § 1.199-3(m)(2)(i) of the proposed regulations clarifies that a taxpayer must engage in construction activities that include more than the approval or authorization of payments or invoices for that taxpayer's activities to be considered as activities typically performed by a general contractor.
Section 1.199-3(m)(2)(i) provides that activities constituting construction are activities performed in connection with a project to erect or substantially renovate real property. Section 1.199-3(m)(5) currently defines substantial renovation to mean the renovation of a major component or substantial structural part of real property that materially increases the value of the property, substantially prolongs the useful life of the property, or adapts the property to a new or different use. This standard reflects regulations under § 1.263(a)-3 related to amounts paid to improve tangible property that existed at the time of publication of the final § 1.199-3(m)(5) regulations (TD 9263 [71 FR 31268] June 19, 2006) but which have since been revised. See (TD 9636 [78 FR 57686] September 19, 2013).
The proposed regulations under § 1.199-3(m)(5) revise the definition of substantial renovation to conform to the final regulations under § 1.263(a)-3, which provide rules requiring capitalization of amounts paid for improvements to a unit of property owned by a taxpayer. Improvements under § 1.263(a)-3 are amounts paid for a betterment to a unit of property, amounts paid to restore a unit of property, and amounts paid to adapt a unit of property to a new or different use. See § 1.263(a)-3(j), (k), and (l). Under the proposed regulations, a substantial renovation of real property is a renovation the costs of which are required to be capitalized as an improvement under § 1.263(a)-3, other than an amount described in § 1.263(a)-3(k)(1)(i) through (iii) (relating to amounts for which a loss deduction or basis adjustment requires capitalization as an improvement). The improvement rules under § 1.263(a)-3 provide specific rules of application for buildings (see § 1.263(a)-3(j)(2)(ii), (k)(2), and (l)(2)), which apply for purposes of § 1.199-3(m)(5).
Section 1.199-4(b)(1) describes how a taxpayer determines its CGS allocable to DPGR. The Treasury Department and the IRS are aware that in the case of transactions accounted for under a long-term contract method of accounting (either the percentage-of-completion method (PCM) or the completed-contract method (CCM)), a taxpayer incurs allocable contract costs. The Treasury Department and the IRS recognize that allocable contract costs under PCM or CCM are analogous to CGS and should be treated in the same manner. Section 1.199-4(b)(1) of the proposed regulations provides that in the case of a long-term contract accounted for under PCM or CCM, CGS for purposes of § 1.199-4(b)(1) includes allocable contract costs described in § 1.460-5(b) or § 1.460-5(d), as applicable.
Existing § 1.199-4(b)(2)(i) provides that a taxpayer must use a reasonable method that is satisfactory to the
Section 199(d)(3)(A) provides that any person who receives a qualified payment from a specified agricultural or horticultural cooperative must be allowed for the taxable year in which such payment is received a deduction under section 199(a) equal to the portion of the deduction allowed under section 199(a) to such cooperative that is (i) allowed with respect to the portion of the QPAI to which such payment is attributable, and (ii) identified by such cooperative in a written notice mailed to such person during the payment period described in section 1382(d).
Under § 1.199-6(c), the cooperative's QPAI is computed without taking into account any deduction allowable under section 1382(b) or section 1382(c) (relating to patronage dividends, per-unit retain allocations, and nonpatronage distributions).
Section 1.199-6(e) provides that the term
Section 1388(f) defines the term
The Treasury Department and the IRS are aware that
Existing § 1.199-3(e)(2) provides that if a taxpayer packages, repackages, labels, or performs minor assembly of QPP and the taxpayer engages in no other MPGE activity with respect to that QPP, the taxpayer's packaging, repackaging, labeling, or minor assembly does not qualify as MPGE with respect to that QPP.
The term
Section 1.199-3(g) of the current regulations, which superseded Notice 2005-14, does not provide a specific definition of minor assembly, but it does allow taxpayers to consider minor assembly activities to determine whether the taxpayer has met the in-whole-or-in-significant-part requirement (either by showing their activities were substantial in nature under § 1.199-3(g)(2) or by meeting the safe harbor in § 1.199-3(g)(3)). However, the current regulations also contain § 1.199-3(e)(2), which excludes certain activities from the definition of MPGE. Section 1.199-3(e)(2) provides that if a taxpayer packages, repackages, labels, or performs minor assembly of QPP and the taxpayer engages in no other MPGE activity with respect to that QPP, the taxpayer's packaging, repackaging, labeling, or minor assembly does not qualify as MPGE with respect to that QPP. Therefore, a taxpayer with only minor assembly activities would not meet the definition of MPGE and a determination of whether a taxpayer met the in-whole-or-in-significant-part requirement is not made.
In considering whether to provide a specific definition of minor assembly, the Treasury Department and the IRS have found it difficult to identify an objective test that would be widely applicable.
The definition of minor assembly could focus on whether a taxpayer's activity is only a single process that does not transform an article into a materially different QPP. Such process may include, but would not be limited to, blending or mixing two materials together, painting an article, cutting, chopping, crushing (non-agricultural products), or other similar activities. An example of blending or mixing two materials is using a paint mixing machine to combine paint with a pigment to match a customer's color selection when a taxpayer did not MPGE the paint or the pigment. An example of cutting is a taxpayer using an industrial key cutting machine to custom cut keys for customers using blank keys that taxpayer purchased from unrelated third parties. Examples of other similar activities include adding an additive to extend the shelf life of a product and time ripening produce that was purchased from unrelated third parties.
Another possible definition could be based on whether an end user could reasonably engage in the same assembly activity of the taxpayer. For example, assume QPP made up of component parts purchased by taxpayer is sold by a taxpayer to end users in either assembled or disassembled form. To the
The Treasury Department and the IRS request comments on how the term
Certain IRS regulations, including this one, are exempt from the requirements of Executive Order 12866 of, as supplemented and reaffirmed by Executive Order 13563. Therefore, a regulatory assessment is not required. It also has been determined that section 553(b) of the Administrative Procedure Act (5 U.S.C. chapter 5) does not apply to these regulations, and because the regulations do not impose a collection of information on small entities, the Regulatory Flexibility Act (5 U.S.C. chapter 6) does not apply. Pursuant to section 7805(f) of the Code, this notice of proposed rulemaking has been submitted to the Chief Counsel for Advocacy of the Small Business Administration for comment on their impact on small business.
Before these proposed regulations are adopted as final regulations, consideration will be given to any written comments (a signed original and eight (8) copies) or electronic comments that are submitted timely to the IRS. Comments are requested on all aspects of the proposed regulations. All comments will be available for public inspection and copying at
A public hearing has been scheduled for December 16, 2015, beginning at 10 a.m. in the Auditorium of the Internal Revenue Building, 1111 Constitution Avenue NW., Washington, DC. Due to building security procedures, visitors must enter at the Constitution Avenue entrance. Because of access restrictions, visitors will not be admitted beyond the immediate entrance area more than 30 minutes before the hearing starts. In addition, all visitors must present photo identification to enter the building. For information about having your name placed on the building access list to attend the hearing, see the
The rules of 26 CFR 601.601(a)(3) apply to the hearing. Persons who wish to present oral comments at the hearing must submit electronic or written comments by November 25, 2015, and an outline of the topics to be discussed and the time to be devoted to each topic by November 25, 2015. A period of 10 minutes will be allotted to each person for making comments. An agenda showing the scheduling of the speakers will be prepared after the deadline for receiving outlines has passed. Copies of the agenda will be available free of charge at the hearing.
The principal author of these regulations is James Holmes, Office of the Associate Chief Counsel (Passthroughs and Special Industries). However, other personnel from the Treasury Department and the IRS participated in their development.
Income taxes, Reporting and recordkeeping requirements.
Accordingly, 26 CFR part 1 is proposed to be amended as follows:
26 U.S.C. 7805 * * *
The additions and revision read as follows:
(f) Oil related qualified production activities income.
(1) In general.
(i) Oil related QPAI.
(ii) Special rule for oil related DPGR.
(iii) Definition of oil.
(iv) Primary product from oil or gas.
(A) Primary product from oil.
(B) Primary product from gas.
(C) Primary products from changing technology.
(D) Non-primary products.
(2) Cost allocation methods for determining oil related QPAI.
(i) Section 861 method.
(ii) Simplified deduction method.
(iii) Small business simplified overall method.
(c) Acquisitions, dispositions, and short taxable years.
(1) Allocation of wages between more than one taxpayer.
(2) Short taxable years.
(3) Operating rules.
(i) Acquisition or disposition.
(ii) Trade or business.
(f) Commonwealth of Puerto Rico.
(h) United States.
(2) Commonwealth of Puerto Rico.
(i) * * *
(9) Engaging in production of qualified films.
(i) In general.
(ii) No double attribution.
(iii) Timing of attribution.
(iv) Examples.
(k) * * *
(10) Special rule for disposition of promotional films and products or services promoted in promotional films.
(b) * * *
(2) * * *
(iii) Cost of goods sold associated with activities undertaken in an earlier taxable year.
(A) In general.
(B) Example.
(i) Effective/applicability dates.
(10) Acquisition or disposition of a trade or business (or major portion).
(11) Energy Improvement and Extension Act of the 2008, Tax Extenders and Alternative Minimum Tax Relief Act of 2008, American Taxpayer Relief Act of 2012, and other provisions.
(f)
(A) The CGS that is allocable to such receipts; and
(B) Other expenses, losses, or deductions (other than the deduction allowed under this section) that are properly allocable to such receipts. See §§ 1.199-3 and 1.199-4.
(ii)
(iii)
(iv)
(A)
(
(
(
(
(
(
(B)
(
(
(
(
(C)
(D)
(2)
(ii)
(iii)
(c) [The text of the proposed amendments to § 1.199-2(c) is the same as the text of § 1.199-2T(c) published elsewhere in this issue of the
(e) * * *
(1) * * * In the case of a qualified film (as defined in § 1.199-3(k)) for taxable years beginning after 2007, the term
(f)
The revisions and additions read as follows:
(d) * * *
(4) * * *
The facts are the same as
Z is engaged in the trade or business of construction under NAICS code 23 on a regular and ongoing basis. Z purchases a piece of property that has two buildings located on it. Z performs construction activities in connection with a project to substantially renovate building 1. Building 2 is not substantially renovated and together building 1 and building 2 are not substantially renovated, as defined under paragraph (m)(5) of this section. Z later sells building 1 and building 2 together in the normal course of Z's business. Z can use any reasonable method to determine what construction activities constitute an item under paragraph (d)(2)(iii) of this section. Z's method is not reasonable if Z treats the gross receipts derived from the sale of building 1 and building 2 as DPGR. This is because Z's construction activities would not have substantially renovated buildings 1 and 2 if they were considered together as one item. Z's method is reasonable if it treats the construction activities with respect to building 1 as the item under paragraph (d)(2)(iii) of this section because the proceeds from the sale of building 1 constitute DPGR.
(e) * * *
(1) * * * Pursuant to paragraph (f)(1) of this section, the taxpayer must be the party engaged in the MPGE of the QPP during the period the MPGE activity occurs in order for gross receipts derived from the MPGE of QPP to qualify as DPGR.
(3) * * * Notwithstanding paragraph (i)(4)(i)(B)(
(5) * * *
* * * A stores the agricultural products. * * *
* * * Y engages in the reconstruction and refurbishment activity and installation of the parts. * * *
The following activities are performed by Z as part of the MPGE of the QPP: Materials analysis and selection, subcontractor inspections and qualifications, testing of component parts, assisting customers in their review and approval of the QPP, routine production inspections, product documentation, diagnosis and correction of system failure, and packaging for shipment to customers. Because Z MPGE the QPP, these activities performed by Z are part of the MPGE of the QPP. If Z did not MPGE the QPP, then these activities, such as testing of component parts, performed by Z are not the MPGE of QPP.
X is in the business of selling gift baskets containing various products that are packaged together. X purchases the baskets and the products included within the baskets from unrelated third parties. X plans where and how the products should be arranged into the baskets. On an assembly line in a gift basket production facility, X arranges the products into the baskets according to that plan, sometimes relabeling the products before placing them into the baskets. X engages in no other activity besides packaging, repackaging, labeling, or minor assembly with respect to the gift baskets. Therefore, X is not considered to have engaged in the MPGE of QPP under paragraph (e)(2) of this section.
(f) * * *
(1) * * * If a qualifying activity under paragraph (e)(1), (k)(1), or (l)(1) of this section is performed under a contract, then the party to the contract that is the taxpayer for purposes of this paragraph (f) during the period in which the qualifying activity occurs is the party performing the qualifying activity.
(4) * * *
X designs machines that it sells to customers. X contracts with Y, an unrelated person, for the manufacture of the machines. The contract between X and Y is a fixed-price contract. To manufacture the machines, Y purchases components and raw materials. Y tests the purchased components. Y manufactures the raw materials into additional components and Y physically performs the assembly of the components into machines. Y oversees and directs the activities under which the machines are manufactured by its employees. X also has employees onsite during the manufacturing for quality control. Y packages the finished machines and ships them to X's customers. Pursuant to paragraph (f)(1) of this section, Y is the taxpayer during the period the manufacturing of the machines occurs and, as a result, Y is treated as the manufacturer of the machines.
(g) * * *
(4) * * *
(i)
(h)
(2)
(i) * * *
(3)
(A) In the case of a hedge of purchases of property described in section 1221(a)(1), income, deduction, gain, or loss on the hedging transaction must be taken into account in determining CGS;
(B) In the case of a hedge of sales of property described in section 1221(a)(1), income, deduction, gain, or loss on the hedging transaction must be taken into account in determining DPGR; and
(C) In the case of a hedge of purchases of property described in section 1221(a)(8), income, deduction, gain, or loss on the hedging transaction must be taken into account in determining DPGR.
(ii)
(iii)
(5) * * *
(iii) * * *
X produces a live television program that is a qualified film. In 2010, X broadcasts the television program on its station and distributes the program through the Internet. The television program contains product placements and advertising for which X received compensation in 2010. Because the methods and means of distributing a qualified film under paragraph (k)(1) of this section do not affect the availability of the deduction under section 199 for taxable years beginning after 2007, pursuant to paragraph (i)(5)(ii) of this section, all of X's product placement and advertising gross receipts for the program are treated as derived from the distribution of the qualified film.
(9)
(ii)
(iii)
(iv)
In 2010, Studio A and Studio B form an S corporation in which each is a 50-percent shareholder to produce a qualified film. Studio A owns the rights to distribute the film domestically and Studio B owns the rights to distribute the film outside of the United States. The production activities of the S corporation are attributed to each shareholder, and thus each shareholder's revenue from the distribution of the qualified film is treated as DPGR during the attribution period because Studio A and Studio B are treated as having directly engaged in any film that was produced by the S corporation.
The facts are the same as
In 2010, Studio A and Studio B form a partnership in which each is a 50-percent partner to distribute a qualified film. Studio A produced the film and contributes it to the partnership and Studio B contributes cash to the partnership. The production activities of Studio A are attributed to the partnership, and thus the partnership's revenue from the distribution of the qualified film is treated as DPGR during the attribution period, as defined in paragraph (i)(9)(iii) of this section, because the partnership is treated as having directly engaged in any film that was produced by Studio A.
The facts are the same as
The facts are the same as
(k) * * *
(1) * * * For taxable years beginning after 2007, the term
(2) * * *
(ii)
(3) * * *
(i) * * * For taxable years beginning after 2007, the methods and means of distributing a qualified film shall not affect the availability of the deduction under section 199.
(6) * * * Production activities do not include transmission or distribution activities with respect to a film, including the transmission of a film by electronic signal and the activities facilitating such transmission (such as formatting that enables the film to be transmitted).
(7) * * *
(i) * * * Paragraph (g)(3)(ii) of this section includes all costs paid or incurred by a taxpayer, whether or not capitalized or required to be capitalized under section 263A, to produce a live or delayed television program, and also includes any lease, rental, or license fees paid by a taxpayer for all or any portion of a film, or films produced by a third party that taxpayer uses in its film. License fees for films produced by third parties are not included in the direct labor and overhead to produce the film for purposes of applying paragraph (g)(3) of this section. * * *
(8) * * * If one party performs a production activity pursuant to a contract with another party, then only the party that is considered the taxpayer pursuant to paragraph (f)(1) of this section during the period in which the production activity occurs is treated as engaging in the production activity.
(10)
(11) * * *
X produces live television programs that are qualified films. X shows the programs on its own television station. X sells advertising time slots to advertisers for the television programs. Because the methods and means of distributing a qualified film under paragraph (k)(1) of this section do not affect the availability of the deduction under section 199 for taxable years beginning after 2007, the advertising income X receives from advertisers is derived from the lease, rental, license, sale, exchange, or other disposition of the qualified films and is DPGR.
* * * Y is considered the taxpayer performing the qualifying activities pursuant to paragraph (f)(1) of this section with respect to the DVDs during the MPGE and duplication process. * * *
X produced a qualified film and licenses the trademark of Character A, a character in the qualified film, to Y for reproduction of the Character A image onto t-shirts. Y sells the t-shirts with Character A's likeness to customers, and pays X a royalty based on sales of the t-shirts. X's qualified film only includes intangibles with respect to the qualified film in taxable years beginning after 2007, including the trademark of Character A. Accordingly, any gross receipts derived from the license of the trademark of Character A to Y occurring in a taxable year beginning before 2008 are non-DPGR, and any gross receipts derived from the license of the trademark of Character A occurring in a taxable year beginning after 2007 are DPGR (assuming all other requirements of this section are met). The royalties X derives from Y occurring in a taxable year beginning before 2008 are non-DPGR because the royalties are derived from an intangible (which is not within the definition of a qualified film under paragraph (k)(1) of this section for taxable years beginning before 2008).
Y, a media company, acquires all of the intangible rights to Book A, which was written and published in 2008, and all of the intangible rights associated with a qualified film that is based on Book A. The qualified film based on Book A is produced in 2009 by Y. Y owns the copyright and trademark to Character B, the lead character in Book A and the qualified film based on Book A. Y licenses Character B's copyright and trademark to Z for $50,000,000. For 2009, without taking into account the payment from Z, Y derives 40 percent of its gross receipts from the qualified film based on Book A, and 60 percent from Book A. Z's payment is attributable to both Book A and the qualified film based on Book A. Therefore, Y must allocate Z's payment, and only the gross receipts derived from licensing the intangible rights associated with the qualified film based on Book A, or 40 percent, are DPGR.
Z produces a commercial in the United States that features Z's shirts, shoes, and other athletic equipment that all have Z's trademarked logo affixed (promoted products). Z's commercial is a qualified film produced by Z. Z sells the shirts, shoes, and athletic equipment to customers at retail establishments. Z's gross receipts are derived from the disposition of the promoted products and are not derived from the disposition of Z's qualified film, including any copyrights, trademarks, or other intangibles with respect to Z's qualified film.
X produces a commercial in the United States that features X's services (promoted services). X's commercial is a qualified film produced by X. The commercial includes Character A developed to promote X's services. Gross receipts that X derives from providing the promoted services are not derived from the disposition of X's qualified film, including any copyrights, trademarks, or other intangibles with respect to X's qualified film. X also licenses the right to reproduce Character A developed to promote X's services to Y so that Y can produce t-shirts featuring Character A. This license is distinct (separate and apart) from a disposition of the promoted services and the gross receipts are derived from the license of an intangible with respect to X's qualified film produced by X. X's gross receipts derived from the license to reproduce Character A are DPGR.
Y produces a qualified film in the United States. Y purchases DVDs and affixes the qualified film to the DVDs. Y purchases gift baskets and sells individual gift baskets that contain a DVD with the affixed qualified film in its retail stores in the normal course of Y's business. Under § 1.199-3(k)(2)(ii)(A), Y may treat the DVD as part of the qualified film produced by taxpayer, but Y cannot treat the gift baskets as part of the qualified film produced by taxpayer. The gross receipts that Y derives from the sale of the DVD are DPGR derived from a qualified film, but the gross receipts that Y derives from the sale of the gift baskets are non-DPGR.
The facts are the same as in
(m) * * *
(2) * * *
(i) * * * A taxpayer whose engagement in the activity is primarily limited to approving or authorizing invoices or payments is not considered engaged in a construction activity as a general contractor or in any other capacity.
(5)
(b) * * *
(1) * * * In the case of a long-term contract accounted for under the percentage-of-completion method described in § 1.460-4(b) (PCM), or the completed-contract method described in § 1.460-4(d) (CCM), CGS for purposes of this section includes the allocable contract costs described in § 1.460-5(b) (in the case of a contract accounted for under PCM) or § 1.460-5(d) (in the case of a contract accounted for under CCM). * * *
(2) * * *
(iii)
(B)
During the 2009 taxable year, X manufactured and sold Product A. All of the gross receipts from sales recognized by X in 2009 were from the sale of Product A and qualified as DPGR. Employee 1 was involved in X's production process until he retired in 2003. In 2009, X paid $30 directly from its general assets for Employee 1's medical expenses pursuant to an unfunded, self-insured plan for retired X employees. For purposes of computing X's 2009 taxable income, X capitalized those medical costs to inventory under section 263A. In 2009, the CGS for a unit of Product A was $100 (including the applicable portion of the $30 paid for Employee 1's medical costs that was allocated to cost of goods sold under X's allocation method for additional section 263A costs). X has information readily available to specifically identify CGS allocable to DPGR and can identify that amount without undue burden and expense because all of X's gross receipts from sales in 2009 are attributable to the sale of Product A and qualify as DPGR. The inventory cost of each unit of Product A sold in 2009, including the applicable portion of retiree medical costs, is related to X's gross receipts from the sale of Product A in 2009. X may not segregate the 2009 CGS by separately allocating the retiree medical costs, which are components of CGS, to DPGR and non-DPGR. Thus, even though the retiree medical costs can be associated with activities undertaken in prior years, $100 of inventory cost of each unit of Product A sold in 2009, including the applicable portion of the retiree medical expense cost component, is allocable to DPGR in 2009.
(m) * * *
(i) The facts are the same as
(ii) Cooperative X is a cooperative described in paragraph (f) of this section. Accordingly, this section applies to Cooperative X and its patrons and all of Cooperative X's gross receipts from the sale of its patrons' corn qualify as domestic production gross receipts (as defined in § 1.199-3(a)). Cooperative X's QPAI is $1,370,000. Cooperative X's section 199 deduction for its taxable year 2007 is $82,200 (.06 × $1,370,000). Because this amount is more than 50% of Cooperative X's W-2 wages (.5 × $130,000 = $65,000), the entire amount is not allowed as a section 199 deduction, but is instead subject to the wage limitation section 199(b), and also remains subject to the rules of section 199(d)(3) and this section.
(i)
(10) [The text of the proposed amendments to § 1.199-8(i)(10) is the same as the text of § 1.199-8T(i)(10) published elsewhere in this issue of the
(11)
Environmental Protection Agency (EPA).
Proposed rule; notice of public hearings.
The Environmental Protection Agency (EPA) is announcing three public hearings to be held for three proposed rules titled, “Source Determination for Certain Emission Units in the Oil and Natural Gas Sector,” “Oil and Natural Gas Sector: Emission Standards for New and Modified Sources,” and “Review of New Sources and Modifications in Indian Country: Federal Implementation Plan for Managing Air Emissions from True Minor Sources Engaged in Oil and Natural Gas Production in Indian Country.” Two hearings will be held on September 23, 2015, simultaneously—one in Denver, CO, and one in Dallas, TX. One hearing will be on September 29, 2015, in Pittsburgh, PA.
Two public hearings will be held at different locations on September 23, 2015, and one public hearing will be held on September 29, 2015.
The September 23, 2015, Denver, CO, hearing will be held at the EPA, Region 8, 1595 Wynkoop Street, Denver, CO 80202. The September 23, 2015, Dallas, TX, hearing will be held at the Dallas City Hall, Council Chambers, 1500 Marilla Street, Dallas, TX 75201. The September 29, 2015, Pittsburgh, PA, hearing will be held at the William S. Moorhead Federal Building, 1000 Liberty Avenue, Pittsburgh, PA 15222. Identification is required at the Denver, CO, and Pittsburgh, PA, hearings because they are being held in federal facilities. If your driver's license is issued by American Samoa, Louisiana, Minnesota, New Hampshire or New York, you must present an additional form of identification to enter (
For information related to these public hearings, please contact Ms. Aimee St. Clair, Office of Air Quality Planning and Standards (E143-03), U.S. Environmental Protection Agency, by phone at (919) 541-1063, or by email at
For questions concerning the proposed rule titled, “Source Determination for Certain Emission Units in the Oil and Natural Gas Sector,” contact Ms. Cheryl Vetter, Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, by phone at (919) 541-4391, or by email at
For questions concerning the proposed rule titled, “Oil and Natural Gas Sector: Emission Standards for New and Modified Sources,” contact Mr. Bruce Moore, Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, by phone at (919) 541-5460, or by email at
For questions concerning the proposed rule titled, “Review of New Sources and Modifications in Indian Country: Federal Implementation Plan for Managing Air Emissions from True Minor Sources Engaged in Oil and Natural Gas Production in Indian Country,” contact Mr. Christopher Stoneman, Office of Air Quality Planning and Standards, U.S. Environmental Protection Agency, by phone at (919) 541-0823, or by email at
The public hearings will be held to accept oral comments on all three proposed rulemakings listed in the summary section of this document. Commenters may choose to speak on one or more of the three proposed rulemakings.
All three hearings will begin at 9:00 a.m. and will conclude at 8:00 p.m. (local time). There will be a lunch break from 12:00 p.m. to 1:00 p.m. (local time) and a dinner break from 5:00 p.m. to 6:00 p.m. (local time). To register to speak at the hearings, please use the online registration form available at
Oral testimony will be limited to 5 minutes for each commenter. The EPA encourages commenters to provide the EPA with a copy of their oral testimony electronically (via email) before the hearings and in hard copy form at the hearings.
The hearings will provide interested parties the opportunity to present data, views, or arguments concerning the proposed actions. The EPA will make every effort to accommodate all speakers who wish to register to speak at the hearing venues on the day of the hearings. The EPA may ask clarifying questions during the oral presentations, but will not respond to the presentations at that time. Written statements and supporting information submitted during the comment period will be considered with the same weight as oral comments and supporting information presented at the public hearings. Verbatim transcripts of the hearings and written statements will be included in the dockets for each rulemaking. The EPA plans for the
Because the Denver, CO, and Pittsburgh, PA, hearings are being held at United States government facilities, individuals planning to attend these hearings should be prepared to show valid picture identification to the security staff in order to gain access to the meeting room. Please note that the REAL ID Act, passed by Congress in 2005, established new requirements for entering federal facilities. If your driver's license is issued by American Samoa, Louisiana, Minnesota, New Hampshire or New York, you must present an additional form of identification to enter the federal building. Acceptable alternative forms of identification include: Federal employee badges, passports, enhanced driver's licenses, and military identification cards. For additional information for the status of your state regarding REAL ID, go to
At all of the hearing locations, atttendees will be asked to go through metal detectors. To help facilitate this process, please be advised that you will be asked to remove all items from all pockets and place them in provided bins for screening; remove laptops, phones, or other electronic devices from their carrying case and place in provided bins for screening; avoid shoes with metal shanks, toe guards, or supports as a part of their construction; remove any metal belts, metal belt buckles, large jewelry, watches; and follow the instructions of the guard if identified for secondary screening. Additionally, no weapons (
The EPA has established separate dockets for all three of the proposed rulemakings (available at
Environmental Protection Agency (EPA).
Proposed rule.
The Environmental Protection Agency (EPA) is proposing three separate and independent determinations related to the 36 areas that are currently classified as “Marginal” for the 2008 ozone National Ambient Air Quality Standards (NAAQS). First, the EPA is proposing to determine that 17 areas attained the 2008 ozone NAAQS by the applicable attainment date of July 20, 2015, based on complete, quality-assured and certified ozone monitoring data for 2012-2014. Second, the EPA is proposing to grant 1-year attainment date extensions for eight areas on the basis that the requirements for such extensions under the Clean Air Act (CAA or Act) have been met. Third, the EPA is proposing to determine that 11 areas failed to attain the 2008 ozone NAAQS by the applicable attainment date of July 20, 2015, and that they are not eligible for an extension, and to reclassify these areas as “Moderate” for the 2008 ozone NAAQS. Once reclassified as Moderate, states must submit State Implementation Plan (SIP) revisions that meet the statutory and regulatory requirements that apply to 2008 ozone NAAQS nonattainment areas classified as Moderate. In this action, the EPA is proposing and taking comment on two options for the deadline by which states would need to submit to the EPA for review and approval the SIP revisions required for Moderate areas once their areas are reclassified.
Submit your comments, identified by Docket ID No. EPA-OAR-2015-0468, to the
Mr. Cecil (Butch) Stackhouse, Office of Air Quality Planning and Standards, Air Quality Policy Division, Mail Code C539-01, Research Triangle Park, NC 27711, telephone (919) 541-5208; fax number: (919) 541-5315; email address:
Entities potentially affected by this action include states (typically state air pollution control agencies), the District of Columbia and, in some cases, tribal governments. In particular, 26 states
• Identify the rulemaking by docket number and other identifying information (subject heading,
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In addition to being available in the docket, an electronic copy of this document will be posted at
To request a public hearing or information pertaining to a public hearing on this document, contact Ms. Pamela Long at (919) 541-0641 before 5 p.m. on September 11, 2015. If requested, further details concerning a public hearing for this proposed rule will be published in a separate
The information presented in this preamble is organized as follows.
CAA section 181(b)(2) requires the EPA Administrator to determine, based on an area's design value (which represents air quality in the area for the most recent 3 year period)
The EPA is proposing in this document to apply the discretion granted to the Administrator in the statute to adjust the statutory deadlines for submitting required SIP revisions for reclassified Moderate ozone nonattainment areas in order to align the SIP due dates with the regulatory deadline for implementing reasonably available control measures (RACM), including reasonably available control technology (RACT), in such areas as necessary to attain the 2008 ozone standard by the Moderate area attainment deadline of July 20, 2018.
On March 12, 2008, the EPA issued its final action to revise the NAAQS for ozone to establish new 8-hour standards (73 FR 16436, March 27, 2008). In that action, we promulgated identical revised primary and secondary ozone standards, designed to protect public health and welfare, that specified an 8-hour ozone standard of 0.075 parts per million (ppm).
On April 30, 2012 (May 31, 2012), the EPA issued rules designating 46 areas throughout the country as nonattainment for the 2008 ozone
Pursuant to a challenge of the EPA's interpretation of the attainment deadlines, on December 23, 2014, the D.C. Circuit issued a decision rejecting, among other things, the Classifications Rule's attainment deadlines for the 2008 ozone nonattainment areas, finding that the EPA did not have statutory authority under the CAA to extend those deadlines to the end of the calendar year.
The statutory authority for the actions proposed in this document is provided by the CAA, as amended (42 U.S.C. 7401
By way of background, CAA section 107(d) provides that when the EPA establishes or revises a NAAQS, the agency must designate areas of the country as nonattainment, attainment, or unclassifiable based on whether they are not meeting (or contributing to air quality in a nearby area that is not meeting) the NAAQS, meeting the NAAQS, or cannot be classified as meeting or not meeting the NAAQS, respectively. Subpart 2 of part D of title I of the CAA governs the classification, state planning and emissions control requirements for any areas designated as nonattainment for a revised primary ozone NAAQS. In particular, CAA section 181(a)(1) requires each area designated as nonattainment for a revised ozone NAAQS to be “classified” at the same time as the area is designated based on the severity of the ozone level in the area (as determined based on the area's “design value,” which represents air quality in the area for the most recent 3 years).
Section 181(b)(2)(A) of the CAA requires that within 6 months following the applicable attainment date, the Administrator will determine whether an ozone nonattainment area attained the ozone standard based on the area's design value as of that date. Section 181(a)(5) of the CAA gives the Administrator the discretion to grant a 1-year extension of the attainment date specified in CAA section 181(a) upon application by any state if: (i) The state has complied with all requirements and commitments pertaining to the area in the applicable implementation plan; and (ii) no more than one measured exceedance of the NAAQS for ozone has occurred in the area preceding the extension year. The EPA may grant a second 1-year extension if these same criteria are met by the end of the first extension year.
Because CAA section 181(a)(5)(B) was written for an exceedance-based standard, such as the 1-hour ozone NAAQS, the EPA has interpreted through notice-and-comment rulemaking the air quality requirement of the extension criteria for purposes of a concentration-based standard like the 2008 8-hour ozone NAAQS. For purposes of determining an area's eligibility for an attainment date extension for the 2008 ozone NAAQS, the EPA has interpreted the criteria of CAA section 181(a)(5)(B) to mean that an area's fourth highest daily maximum 8-hour value for the attainment year
In the event an area fails to attain the relevant ozone NAAQS by the applicable attainment date, CAA section 181(b)(2)(A) requires the Administrator to make the determination that an ozone nonattainment area failed to attain the ozone standard by the applicable attainment date, and subsequently requires the area to be reclassified by operation of law to the higher of (i) the next higher classification for the area, or (ii) the classification applicable to the area's design value as determined at the time of the required
Once an area is reclassified, the EPA must address the schedule by which the state is required to submit a revised SIP for that area to, among other things, demonstrate how the area will attain the relevant NAAQS as expeditiously as practicable but no later than the new
Under EPA regulations at 40 CFR part 50, appendix P, the 2008 ozone NAAQS is attained at a site when the 3-year average of the annual fourth highest daily maximum 8-hour average ambient air quality ozone concentration is less than or equal to 0.075 ppm. This 3-year average is referred to as the design value. When the design value is less than or equal to 0.075 ppm at each ambient air quality monitoring site within the area, then the area is deemed to be meeting the NAAQS. The rounding convention under 40 CFR part 50, appendix P, dictates that concentrations shall be reported in ppm to the third decimal place, with additional digits to the right being truncated. Thus, a computed 3-year average ozone concentration of 0.076 ppm is greater than 0.075 ppm and, therefore, over the standard.
The EPA's determination of attainment is based upon data that have been collected and quality-assured in accordance with 40 CFR part 58 and recorded in the EPA's Air Quality System database (formerly known as the Aerometric Information Retrieval System). Ambient air quality monitoring data for the 3-year period must meet a data completeness requirement. The ambient air quality monitoring data completeness requirement is met when the average percent of required monitoring days with valid ambient monitoring data is greater than 90 percent, and no single year has less than 75 percent data completeness as determined according to Appendix P of part 50.
The EPA is issuing this proposal pursuant to the agency's statutory obligation under CAA section 181(b)(2) to determine whether the 36 Marginal ozone nonattainment areas have attained the 2008 ozone NAAQS by the applicable attainment date of July 20, 2015. The separate actions being taken in this proposal, as well as the rationale for these actions, are described in the sections below.
The EPA evaluated data from air quality monitors in the 36 Marginal nonattainment areas for the 2008 ozone NAAQS in order to determine the areas' attainment status as of the applicable attainment date of July 20, 2015. The data were supplied and quality assured by state and local agencies responsible for monitoring ozone air monitoring networks. Seventeen of the 36 nonattainment areas' monitoring sites with valid data had a design value equal to or less than 0.075 ppm based on the 2012-2014 monitoring period. Thus, the EPA proposes to determine, in accordance with section 181(b)(2)(A) of the CAA and the provisions of the SIP Requirements Rule (40 CFR 51.1103), that these 17 areas (listed in Table 2 below) attained the standard by the applicable attainment date for Marginal nonattainment areas for the 2008 ozone NAAQS. The EPA's determination is based upon 3 years of complete, quality-assured and certified data. Table 2 displays the 2012-2014 design value for these 17 areas. The fourth high values for each of the 3 years used to calculate each monitor's 2012-2014 design value are provided in the technical support document (TSD) in the docket for this action.
Of the 36 Marginal nonattainment areas for the 2008 ozone NAAQS, there are eight areas for which the EPA is proposing to grant a 1-year attainment date extension based on determinations that these areas have met the requirements for an extension under CAA section 181(a)(5).
Specifically, for each of the eight nonattainment areas, the EPA received a letter from a state air agency requesting a 1-year extension of the area's attainment date and certifying that the state is in compliance with the applicable implementation plan, as required under CAA section 181(a)(5)(A). In their requests, the states certified that they have complied with all requirements and commitments pertaining to their respective nonattainment areas in the applicable implementation plan and that all monitors in the area have a fourth highest daily maximum 8-hour average
The EPA has also evaluated the certified air quality monitoring data for 2014 and is proposing to determine that each of the eight areas listed in Table 3 meets the air quality requirements of CAA section 181(a)(5)(B) and the EPA's interpretation of that statutory provision in 40 CFR 51.1107. As explained in Section II.C of this preamble, the EPA has interpreted the air quality criterion in CAA section 181(a)(5)(B) for purposes of the 2008 8-hour standard to mean that an eligible area's fourth highest daily maximum 8-hour average in the year preceding the attainment date is equal to or below the NAAQS (80 FR 12292). The EPA has evaluated the data for these eight areas and has determined that the fourth highest daily maximum 8-hour average for each area in 2014 is equal to or below 0.075 ppm. Table 3 provides the fourth highest daily maximum 8-hour averages for 2014 for each of the eight Marginal nonattainment areas for which a state has requested an attainment date extension.
Based on the EPA's evaluation and determination that eight Marginal nonattainment areas for the 2008 ozone NAAQS that failed to attain the NAAQS by July 20, 2015, have met the attainment date extension criteria of CAA section 181(a)(5), the EPA is exercising its discretion to propose granting a 1-year extension of the applicable Marginal area attainment date to July 20, 2016, from July 20, 2015, for the nonattainment areas listed in Table 3. If this proposal is finalized, then the nonattainment areas would remain classified as Marginal for the 2008 ozone NAAQS unless and until the EPA makes a determination that the areas have not attained the NAAQS by the July 20, 2016, attainment date. The EPA is soliciting comments on this proposal.
The EPA is proposing to determine that 11 Marginal nonattainment areas (listed in Table 4) have failed to attain the 2008 ozone NAAQS by the applicable attainment date of July 20, 2015. These areas are not eligible for a 1-year attainment date extension because the fourth highest daily maximum 8-hour average for at least one monitor in each area is greater than 0.075 ppm for 2014 (
CAA section 181(b)(2)(A) provides that a Marginal nonattainment area shall be reclassified by operation of law upon a determination by the EPA that such area failed to attain the relevant NAAQS by the applicable attainment date. Based on quality-assured ozone monitoring data from 2012-2014, as provided in the TSD for this proposal, the new classification applicable to each of these 11 areas would be the next higher classification of “Moderate” under the CAA statutory scheme.
Moderate nonattainment areas are required to attain the standard “as expeditiously as practicable” but no later than 6 years after the initial designation as nonattainment (which, in the case of these 11 areas, is July 20, 2018). The attainment deadlines associated with each classification are prescribed by the Act and codified at 40 CFR 51.1103.
We also note that the states with areas that attain the 2008 ozone NAAQS after they are reclassified to Moderate can use the EPA's existing Clean Data Policy. The state with areas attaining the NAAQS could also submit a complete redesignation request with a maintenance plan to the EPA prior to the SIP revision deadline that uses the EPA's redesignation guidance.
There are a number of significant emission reduction programs that will lead to reductions of ozone precursors, and that are in place today or are expected to be in place by 2017 to meet the July 20, 2018 attainment date for the 2008 ozone NAAQS Moderate areas. Examples of such rules include state
For each new Moderate ozone nonattainment area, the states responsible for managing air quality in the 11 areas identified in Table 4 will be required to submit a revised SIP that addresses the CAA's Moderate nonattainment area requirements, as interpreted and described in the final SIP Requirements Rule for the 2008 ozone NAAQS.
As noted elsewhere in this preamble, when an area is reclassified under CAA section 181(b)(2), CAA section 182(i) directs that the state shall meet the new requirements according to the schedules prescribed in those requirements. It provides, however, “that the Administrator may adjust any applicable deadlines (other than attainment dates) to the extent such adjustment is necessary or appropriate to assure consistency among the required submissions.” CAA section 182(b), as interpreted by 40 CFR 51.1100
In determining an appropriate deadline for the Moderate area SIP revisions for these 11 areas, the EPA notes that pursuant to 40 CFR 51.1108(d), for each nonattainment area, the state must provide for implementation of all control measures needed for attainment no later than the beginning of the attainment year ozone season. The attainment year ozone season is the ozone season immediately preceding a nonattainment area's attainment date. In the case of nonattainment areas classified as Moderate for the 2008 ozone NAAQS, the attainment year ozone season is the 2017 ozone season (40 CFR 51.1100(g)). The ozone season is the ozone monitoring season as defined in 40 CFR part 58, appendix D, section 4.1, Table D-3 (October 17, 2006, 71 FR 61236). We note that the EPA has proposed changes to the ozone monitoring season in its most recent proposal to revise the ozone NAAQS (79 FR 75234, December 17, 2014). For the purposes of reclassification for the 11 Marginal nonattainment areas identified in this proposal, Table 5 provides the starting month of the ozone monitoring season for each state with one of the 11 Marginal areas as currently codified in the EPA's regulations. Table 5 also includes the December 17, 2014, proposed changes, if any, to the beginning of the ozone monitoring season in such states. If the proposed changes to the beginning of the ozone
Therefore, the EPA is proposing and taking comment on two options for setting the date by which states with jurisdiction for these 11 reclassified nonattainment areas would be required to submit for EPA review and approval SIP revisions to address Moderate area requirements. The first option, which is reflected in Table 5 below, would require that states submit the required SIP revisions as expeditiously as practicable, but no later than the beginning of the ozone season in 2017 for each state. This proposed option would align the SIP submittal deadline with the deadline for implementing applicable controls, which, as noted above, is also no later than the beginning of the ozone season in 2017 for each area. This option would give 9 states additional time that may be needed to accomplish planning, administrative and SIP revision processes. This option would treat states consistently in that they would need to have submitted SIP revisions by the beginning of their respective ozone seasons, but it would result in SIP submittal dates that vary among the states. In addition, as noted above, if the EPA finalizes the proposed changes to the start dates of the ozone season in a number of states, the proposed deadlines for SIP revisions in this rulemaking would also change accordingly. Under this first option, in multi-state nonattainment areas, such as the Chicago-Naperville area, where the three affected states do not have the same ozone season start date, the deadline for the entire nonattainment area would be the earliest ozone season start date for any of the states (
Under the second option, the EPA proposes that the deadline for the required SIP revisions for areas that would be reclassified under this rulemaking would be as expeditiously as practicable, but no later than January 1, 2017. By establishing a single specific submittal date, this option would establish a consistent deadline for all 11 areas, similar to the single uniform SIP submission deadline that would have applied to all areas if they had been initially classified as Moderate. A uniform deadline of January 1, 2017, is reasonable because it would provide all states with approximately 1 year after these reclassifications are finalized to develop complete SIP submissions, and it is the latest SIP submittal date that would be compatible with ensuring controls are in place no later than the start of the attainment year ozone season for all of the 11 reclassified areas.
The EPA solicits comments on both of these proposed options for deadlines to submit the required SIP revisions that would apply to states after any current Marginal nonattainment area for the 2008 ozone NAAQS is reclassified to Moderate.
With regard to the New York-N. New Jersey-Long Island (NY-NJ-CT) nonattainment area, the EPA notes that in addition to the actions related to the 2008 ozone standard addressed in this
One option proposed by the EPA in the May 2014 proposal document would permit the relevant states to respond to the final SIP Call by requesting to be reclassified to Moderate for the 2008 ozone standard (
The public comment period for the May 2014 proposal document closed on June 16, 2014, and the EPA is reviewing comments received on the proposal. However, given that this action proposes to find that the New York-N. New Jersey-Long Island nonattainment area has failed to attain the 2008 ozone standard by its Marginal attainment date of July 20, 2015, and must be reclassified to Moderate by operation of law in accordance with CAA section 181(b)(2)(A), this proposed action would effectively eliminate the need for the three affected states to request reclassification for the area under the option described in the May 2014 proposal document. Although we are not taking final action in this document on the proposed CDD rescission and SIP Call (79 FR 27830), the actions which may occur pursuant to this proposal (
The actions proposed in this document affect the 36 nonattainment areas for the 2008 ozone NAAQS that were initially designated and classified Marginal effective July 20, 2012, based on their individual design values. The design value of an area is represented by the annual fourth-highest daily maximum 8-hour average ozone concentration measured at each monitor in the area, averaged over a consecutive 3-year period. According to CAA section 181(a)(1), as interpreted by EPA regulations at 40 CFR 51.1103, nonattainment Marginal areas are required to attain the standard “as expeditiously as practicable” but no later than 3 years after the designation effective date of July 20, 2012 (
Upon application by any state, the Administrator may extend the 2008 ozone attainment date by 1 year, in accordance with CAA section 181(a)(5) and 40 CFR 51.1107, provided that the state has complied with all requirements and commitments pertaining to the area in the applicable implementation plan, and the area's fourth highest daily maximum 8-hour average value for the last full year of air quality data prior to the July 20, 2015, attainment date (
For the 17 remaining 2008 ozone NAAQS nonattainment areas currently classified as Marginal, the EPA is proposing to determine that each area has ozone design values for the 2012-14 period at or below 0.075 ppm, and, thus, each area has attained the NAAQS by the attainment date of July 20, 2015. The 17 areas are: Allentown-Bethlehem-Easton, PA; Baton Rouge, LA; Calaveras County, CA; Charlotte-Gastonia-Rock Hill, NC-SC; Chico (Butte County), CA; Cincinnati, OH-KY-IN; Columbus, OH; Dukes County, MA; Jamestown, NY; Knoxville, TN; Lancaster, PA; Memphis, TN-MS-AR; Reading, PA; San Francisco
The CAA requires that states with areas designated as nonattainment submit to the Administrator the appropriate SIP revisions and implement specified control measures by certain dates applicable to the area's classification. By requiring additional planning and implementation requirements for the 11 nonattainment areas proposed to be reclassified from Marginal to Moderate, the part of this action reclassifying the areas from Marginal to Moderate will protect all those residing, working, attending school, or otherwise present in those areas regardless of minority or economic status.
This action is not a significant regulatory action and was, therefore, not submitted to the Office of Management and Budget (OMB) for review.
The information collection activities associated with this proposed rule were submitted for approval to the OMB under the PRA as part of the information collection assessment for the 2008 ozone NAAQS SIP Requirements Rule. The Information Collection Request (ICR) document prepared by the EPA has been assigned the EPA ICR number 2347.01. You can find a copy of the ICR in the docket for the 2008 ozone NAAQS SIP Requirements Rule
The EPA issued the 2008 ozone NAAQS SIP Requirements Rule to provide states with assistance in interpreting how CAA requirements apply to their nonattainment areas when the states develop their SIPs for attaining and maintaining the 2008 ozone NAAQS. The intended effect of the SIP Requirements Rule—in conjunction with other rules that address additional aspects of implementation, such as this proposed action—is to provide assistance to states regarding their planning obligations such that states may begin SIP development. In preparing its analysis of the estimated paperwork burden associated with the SIP Requirements Rule and additional rules providing clarity on implementation of the 2008 ozone NAAQS, the EPA calculated that burden for the 46 areas designated non-attainment under that standard.
States should already have information from emission sources, as facilities should have provided this information to meet 1-hour and 1997 8-hour ozone NAAQS SIP requirements, operating permits and/or emissions reporting requirements. Such information does not generally reveal the details of production processes. But, to the extent it may, CBI for the affected facilities is protected. Specifically, submissions of emissions and control efficiency information that is confidential, proprietary and trade secret is protected from disclosure under the requirements of subsections 503(e) and 114(c) of the CAA.
The annual burden for the information collection associated with all 46 nonattainment areas, averaged over the first 3 years of the ICR, was estimated to be a total of 120,000 labor hours per year at an annual labor cost of $2.4 million (present value) over the 3-year period, or approximately $91,000 per state for the 25 state respondents and the District of Columbia. The average annual reporting burden is 690 hours per response, with approximately two responses per state for 58 state responses.
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. The OMB control numbers for the EPA's regulations in 40 CFR are listed in 40 CFR part 9.
The comment period on the agency's need for this information ran from June 6, 2013, to August 5, 2013.
I certify that this action will not have a significant economic impact on a substantial number of small entities under the RFA. This action will not impose any requirements on small entities. The proposed determinations of attainment and failure to attain the 2008 ozone NAAQS (and resulting reclassifications), and the proposed determination to grant 1-year attainment date extensions do not in and of themselves create any new requirements beyond what is mandated by the CAA. Instead, this rulemaking only makes factual determinations, and does not directly regulate any entities.
This action does not contain any unfunded mandate as described in UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect small governments. This action imposes no enforceable duty on any state, local or tribal governments or the private sector.
This action does not have federalism implications. It will not have substantial direct effects on the states, on the relationship between the national government and the states, or on the distribution of power and responsibilities among the various levels of government.
This action has tribal implications. However, it will neither impose substantial direct compliance costs on federally recognized tribal governments, nor preempt tribal law. The EPA has identified a number of tribal areas implicated in the 36 areas covered by the EPA's proposed determinations of attainment and failure to attain the 2008 ozone NAAQS (and resulting reclassifications), and the proposed determination to grant 1-year attainment date extensions. We intend to communicate with potentially affected tribes located within the boundaries of the nonattainment areas for the 2008 ozone NAAQS as we move forward in developing a final rule.
The EPA interprets Executive Order 13045 as applying only to those regulatory actions that concern environmental health or safety risks that the EPA has reason to believe may disproportionately affect children, per the definition of “covered regulatory action” in section 2-202 of the Executive Order. This action is not subject to Executive Order 13045 because it does not concern an environmental health risk or safety risk.
This action is not subject to Executive Order 13211, because it is not a significant regulatory action under Executive Order 12866.
This rulemaking does not involve technical standards.
The EPA believes the human health or environmental risk addressed by this action will not have potential disproportionately high and adverse human health or environmental effects on minority, low-income or indigenous populations. The results of this evaluation are contained in the section of the preamble titled “Environmental Justice Considerations.”
Environmental protection, Air pollution control, Incorporation by reference, Intergovernmental relations, Nitrogen oxides, Ozone, Reporting and recordkeeping requirements, Volatile organic compounds.
42 U.S.C. 7401
Environmental Protection Agency (EPA).
Proposed rule.
The Environmental Protection Agency (EPA) is proposing to approve an element of a State Implementation Plan (SIP) submission from the State of Kansas addressing the applicable requirements of Clean Air Act (CAA) section 110 for the 2008 National Ambient Air Quality Standards (NAAQS) for Ozone (O
Comments on this proposed action must be received in writing by September 28, 2015.
Submit your comments, identified by Docket ID No. EPA-R07-OAR-2015-0512, by mail to Lachala Kemp, Environmental Protection Agency, Air Planning and Development Branch, 11201 Renner Boulevard, Lenexa, Kansas 66219. Comments may also be submitted electronically or through hand delivery/courier by following the detailed instructions in the
Lachala Kemp, Environmental Protection Agency, Air Planning and Development Branch, 11201 Renner Boulevard, Lenexa, Kansas 66219 at (913) 551-7214 or by email at
In the final rules section of this
Environmental protection, Air pollution control, Incorporation by reference, Intergovernmental relations, Ozone, Reporting and recordkeeping requirements.
Environmental Protection Agency (EPA).
Proposed rule.
The Environmental Protection Agency (EPA) is proposing to approve revisions to the New Mexico State Implementation Plan (SIP) for the City of Albuquerque-Bernalillo County. These revisions provide updates to the City of Albuquerque-Bernalillo County major Nonattainment New Source Review (NNSR) permit program. The EPA is proposing this action under section 110 and part D of the Clean Air Act (CAA or the Act).
Comments must be received on or before September 28, 2015.
Submit your comments, identified by Docket ID No. EPA-R06-OAR-2009-0648, by one of the following methods:
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•
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Ms. Erica Le Doux, (214) 665-7265,
Throughout this document whenever “we,” “us,” or “our” is used, we mean the EPA.
The Act at section 110(a)(2)(C) requires states to develop and submit to the EPA for approval into the state SIP, preconstruction review programs applicable to new and modified stationary sources of air pollutants for attainment and nonattainment areas that cover both major and minor new sources and modifications, collectively referred to as the NSR SIP. The CAA NSR SIP program is composed of three separate programs: Prevention of Significant Deterioration (PSD), NNSR, and Minor NSR. PSD is established in part C of title I of the CAA and applies in areas that are designated as meeting the National Ambient Air Quality Standards (NAAQS),
On August 16, 2010, the Governor Bill Richardson submitted revisions to the New Mexico SIP that incorporated revisions to the NMAC for the City of Albuquerque-Bernalillo County. The August 16, 2010, submittal includes final revised regulation sections 1, 2, 6, 7, 12 through 27 (including five new additional sections) in 20.11.60 NMAC, Permitting in Nonattainment Areas. The updates that were accepted by the Albuquerque-Bernalillo County Air Quality Control Board constitutes the integration of language that is consistent with federal NNSR permitting regulations.
On July 26, 2013, the designee of the Governor, New Mexico Environment Department Cabinet Secretary, Ryan Flynn, submitted revisions to the SIP. This SIP submittal incorporated revisions to the NMAC for the City of Albuquerque-Bernalillo County. It includes final revised regulation sections 6, 7, 12, 13, and 15 in 20.11.60 NMAC, Permitting in Nonattainment Areas. The updates that were accepted by the Albuquerque-Bernalillo County Air Quality Control Board constitutes the integration of language that is consistent with federal NNSR permitting regulations.
The EPA also received in the August 16, 2010 submittal revisions to regulations within 20.11.61 NMAC—Prevention of Significant Deterioration (PSD) permitting program and Infrastructure SIP for Particulate Matter less than 2.5 Micrometers (PM
The current SIP-approved version of 20.11.60 NMAC, Permitting in Nonattainment Areas, was last approved by EPA on April 26, 2007, and became effective on May 29, 2007.
• Implementation of the NSR Program for PM
• PSD for PM
• Final Rule to Implement the 8-hour Ozone (O
• PSD and NNSR: Reasonable Possibility in Recordkeeping (72 FR 72607); and
• PSD and NNSR: Reconsideration of Inclusion of Fugitive Rule; Interim Rule; Stay and Revisions (76 FR 17548).
Further, the amendments contained in the two submittals revise the rules to conform to the latest changes to New Mexico Air Code for the City of Albuquerque-Bernalillo County laws which must continue to meet minimum federal requirements and include grammatical and formatting corrections. In addition, more headings were added to provide clarity to the rules.
The EPA's evaluation of the revisions to the New Mexico SIP for the City of Albuquerque-Bernalillo County NNSR program included a line-by-line comparison in the TSD of the proposed revisions with the federal requirements. State and local permitting authorities may meet the requirements of 40 CFR part 51 with different but equivalent regulations. While some permitting authorities choose to incorporate by reference the applicable federal rules, other permitting authorities (such as the City of Albuquerque-Bernalillo County) choose to draft rules that track the federal language but contain differences. We found that in most cases, the state regulatory language is identical to the federal rule. Where the rules are not identical, they are at least consistent and support the federal rules and definitions. The EPA is therefore making a preliminary determination that the City of Albuquerque-Bernalillo County has adopted the necessary elements for the NNSR program to comply with the federal regulatory requirements for implementation of the PM
We evaluated and are proposing to approve the revisions to 20.11.60 NMAC submitted for SIP inclusion on August 16, 2010 and July 26, 2013. The EPA has made the preliminary determination that the revisions are approvable because the submitted rules are adopted and submitted in accordance with the CAA and are consistent with the EPA's regulations for NNSR permitting at 40 CFR 51.160-51.165. Therefore, under section 110 and part D of the Act, and for the reasons presented above and our accompanying TSD, the EPA proposes to fully approve the specific revisions to the New Mexico SIP for the City of Albuquerque-Bernalillo County as identified below.
• Revisions to 20.11.60.1 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.2 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.6 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010; and adopted on April 10, 2013 and submitted on July 26, 2013
• Revisions to 20.11.60.7 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010; and adopted on April 10, 2013 and submitted on July 26, 2013
• Revisions to 20.11.60.12 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010; and adopted on April 10, 2013 and submitted on July 26, 2013
• Revisions to 20.11.60.13 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010; and adopted on April 10, 2013 and submitted on July 26, 2013
• New 20.11.60.14 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• New 20.11.60.15 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010; and adopted on April 10, 2013 and submitted on July 26, 2013
• New 20.11.60.16 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.17 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.18 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• New 20.11.60.19 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• New 11.60.20 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.21 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.22 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.23 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.24 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.25 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.26 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
• Revisions to 20.11.60.27 NMAC as adopted on July 14, 2010 and submitted on August 16, 2010;
The EPA is proposing to find that the August 16, 2010 and July 26, 2013, submittals together addresses all required NNSR elements for the implementation of the 8-hour ozone NAAQS and the 1997 and 2006 PM
In this action, we are proposing to include in a final rule regulatory text that includes incorporation by reference. In accordance with the requirements of 1 CFR 51.5, we are proposing to incorporate by reference
Under the CAA, the Administrator is required to approve a SIP submission that complies with the provisions of the CAA and applicable Federal regulations. See, 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 proposes to approve 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 Order 12866 (58 FR 51735, October 4, 1993);
• 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, 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 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, Carbon monoxide, Incorporation by reference, Intergovernmental relations, Nitrogen dioxide, Particulate matter, Reporting and recordkeeping requirements, Sulfur oxides.
42 U.S.C. 7401
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Proposed rule, request for comments.
NMFS proposes management measures recommended by the New England Fishery Management Council in Framework Adjustment 4 to the Atlantic Herring Fishery Management Plan to further enhance catch monitoring and address discarding in the herring fishery. NMFS proposes measures that would clarify the slippage definition (
Public comments must be received by September 28, 2015.
The New England Fishery Management Council developed an environmental assessment (EA) for this action that describes the proposed action and other considered alternatives and provides a thorough analysis of the impacts of the proposed measures and alternatives. Copies of the framework, the EA, and the Regulatory Impact Review (RIR)/Initial Regulatory Flexibility Analysis (IRFA), are available upon request from Thomas A. Nies, Executive Director, New England Fishery Management Council, 50 Water Street, Newburyport, MA 01950. The EA/RIR/IRFA is accessible via the Internet at
You may submit comments on this document, identified by NOAA-NMFS-2015-0067, by any of the following methods:
• Electronic Submission: Submit all electronic public comments via the Federal e-Rulemaking Portal. Go to
• Mail: John K. Bullard, Regional Administrator, NMFS, Northeast Regional Office, 55 Great Republic Drive, Gloucester, MA 01930. Mark the outside of the envelope, “Comments on the Herring Framework Adjustment 4 Proposed Rule.”
• Fax: (978) 281-9135, Attn: Carrie Nordeen.
Written comments regarding the burden-hour estimates or other aspects of the collection-of-information requirements contained in this proposed
Carrie Nordeen, Fishery Policy Analyst, phone 978-281-9272, fax 978-281-9135.
The Council adopted Framework Adjustment 4 to the Atlantic Herring Fishery Management Plan at its April 22, 2014, meeting. The Council submitted Framework 4 to NMFS for review on July 18, 2014, and resubmitted to NMFS on February 27, 2015, and April 30, 2015.
This proposed rule includes management measures recommended by the Council in Framework 4 intended to further enhance catch monitoring and address discarding in the herring fishery. If implemented, Framework 4 would clarify the slippage definition, require limited access herring vessels to report slippage events on the daily vessel monitoring system (VMS) catch report, and establish slippage consequences. Slippage consequence measures would require vessels with All Areas (Category A) or Areas 2/3 (Category B) Limited Access Herring Permits to move 15 nautical miles (27.78 km) following an allowable slippage event, slippage due to safety, mechanical failure, or excess catch of spiny dogfish, and to terminate a fishing trip and return to port following a non-allowable slippage event, slippage for any other reason.
This proposed rule includes two additional management measures also recommended by the Council in Framework 4. These measures include requiring volumetric catch estimates to be collected aboard vessels with limited access herring permits and requiring vessels with Category A or B herring permits to have fish holds empty of fish when departing on a herring trip. NMFS specifically seeks public comment on the consistency of these measures with the Magnuson-Stevens Fisheries Conservation and Management Act (MSA) and other applicable law.
Additionally, this proposed rule contains minor corrections to existing regulations. NMFS proposes these adjustments under the authority of section 305(d) to the MSA, which provides that the Secretary of Commerce may promulgate regulations necessary to ensure that adjustments to a fishery management plan (FMP) are carried out in accordance with the FMP and the MSA. These adjustments, which are identified and described below, are necessary to clarify current regulations or the intent of the Herring FMP, and would not change the intent of any regulations.
The proposed regulations are based on the measures in Framework 4. The Council developed Framework 4 to build on catch monitoring improvements implemented in Amendment 5 to the Herring FMP (79 FR 8786, February 13, 2014) and to address dealer reporting requirements and slippage caps that NMFS disapproved as part of Amendment 5.
NMFS supports improvements to fishery dependent data collections and shares the Council's concern for reducing unnecessary discarding. During the development of Framework 4, NMFS expressed concern with the lack of rationale supporting two of the measures in Framework 4, specifically the measures requiring volumetric estimates of total catch and empty fish holds at the beginning of a trip. The Council did not provide evidence of specific problems with catch monitoring or discarding that these measures would address, nor did it demonstrate how these measures would rectify any such problems. Therefore, NMFS urged the Council to ensure Framework 4 provided adequate justification to support these measures. At this time, NMFS does not consider Framework 4 to contain sufficient justification for these measures and NMFS remains concerned that the utility of these measures does not outweigh the compliance, administration, and enforcement costs.
This proposed rule describes concerns about these measures' consistency with the MSA and other applicable law. Following public comment, NMFS will determine if these two measures can be approved or if they must be disapproved. NMFS seeks public comment on all proposed measures in Framework 4, and, in particular, NMFS seeks public comment on the proposed requirements for volumetric estimates of total catch and empty fish holds at the beginning of a trip and whether these measures should be approved or disapproved.
Framework 4 would require vessels with limited access herring permits to have their fish holds certified and Northeast Fisheries Science Center (NEFOP) observers to collect volumetric estimates of total catch by measuring the volume of fish in the hold prior to offloading. Observers would convert the volumetric estimate to a weight and submit the estimated weight to the Greater Atlantic Regional Fisheries Office (GARFO) for a cross-check of vessel trip reports (VTRs) and dealer reports.
Vessels with limited access herring permits that store herring catch in fish holds would be required to certify the capacity of their fish holds and mark their holds at regular intervals to facilitate collection of volumetric catch estimates. The fish hold capacity measurement would need to be certified by one of the following entities: (1) A Certified Marine Surveyor with a fishing specialty by the National Association of Marine Surveyors (NAMS); (2) an Accredited Marine Surveyor with a fishing specialty by the Society of Accredited Marine Surveyors (SAMS); (3) employees or agents of a classification society approved by the U.S. Coast Guard pursuant to 46 U.S.C. 3316(c); (4) the Maine State Sealer of Weights and Measures; (5) a professionally-licensed and/or registered Marine Engineer; or (6) a Naval Architect with a professional engineer license. This proposed list of entities is consistent with the list of entities approved to certify fish hold capacities in the Atlantic Mackerel, Squid, and Butterfish FMP. As part of the limited access herring permit renewal process in 2016, vessel owners would be required to submit a certified fish hold capacity measurement to NMFS with a signed certification by the individual or entity that completed the measurement specifying how they met the definition of a qualified individual or entity.
Regulations in the State of Maine already require that herring vessels have their fish holds measured and “sealed” by the State Sealer of Weights and Measures. Additionally, regulations at 50 CFR 648.4(a)(5)(iii)(H)(
Vessels with limited access herring permits would be required to obtain and retain on board a NMFS-approved measuring stick that would be available to the observer to measure the amount of fish in the fish hold. At the completion of a fishing trip, but prior to offloading, the observer would lower the NMFS-approved measuring stick into the fish hold(s) to measure the amount of fish and then estimate the total
Currently, observers do not estimate total catch in the herring fishery. Estimating the volume of fish in fish holds is an accepted practice elsewhere in the world, particularly Europe, to estimate the weight of total catch. However, requiring observers in the herring fishery to collect volumetric estimates of total catch would necessitate significant development of this measure prior to implementation, including developing a sampling protocol, approving volume to weight conversions and deductions to account for water in the fish hold, training observers, and evaluating how to use the data. Additionally, observers in the herring fishery are not currently required to stay with the vessel after landing and contracts for observers do not include sampling responsibilities when the vessel is in port. Requiring observers to sample vessels in port would require modifications to the description of observer duties and contracts with observer service providers.
The requirement for observers to estimate the amount of catch in the fish hold is intended to enhance catch monitoring in the herring fishery by providing an independent estimate of total catch. This measure was developed to address stakeholder concerns with NMFS's reliance on industry-reported catch data to monitor the herring fishery. Specifically, some stakeholders, including environmental organizations, the groundfish industry, and recreational fishing groups, believe that herring catch is not accurately reported by the industry and that large discrepancies exist between vessel and dealer reports. The herring industry, in general, does not believe that herring catch is being misreported but, in an effort to address stakeholder concerns, supports the requirement for observers to collect an estimate of total catch.
Vessels and dealers report catch by species. VTRs, in combination with observer data, are used by NMFS in herring stock assessments and to track catch against catch caps in the herring fishery, while dealer data are used to track catch against herring annual catch limits. The proposed measure would provide an estimate of total catch, but not catch by species. Therefore, the volumetric estimate could not be used to replace either VTRs or dealer data and it could not be used for catch monitoring or stock assessments. While the data generated under this proposed measure would not replace industry-reported data used for quota monitoring and stock assessments, it is intended to help measure the utility of industry-reported catch data, identify, catch reporting issues, and alleviate concerns that vessel operators and dealers collude to misreport catch.
Framework 4 does not provide evidence of misreporting by the herring industry, but it does highlight past differences between the amount of herring reported by vessels and dealers. Prior to 2008, discrepancies between VTRs and dealer data ranged from 4 percent to 54 percent. The vessel hail estimate (reported on the VTR) is different than amount of fish purchased (reported by dealers) so differences between these data sets are expected. However, discrepancies between VTR and dealer data greater than 10 percent are considered substantial.
In recent years, discrepancies between VTRs and dealer data have been minimal. VTRs were higher than dealer reports in 2009 (2 percent), 2010 (1.3 percent), 2011 (1.2 percent), and 2013 (0.1 percent) and less than dealer reports in 2012 (0.1 percent). As described in NMFS's April 17, 2014, letter to the Council, GARFO has improved the process for cross-checking and resolving differences between VTR and dealer data. Staff use advanced programming to match VTR and dealer data for each trip and identify records that do not match. They then investigate each unmatched record to determine the cause of the discrepancy and make the correction to the appropriate data set. This investigation process includes interviews with dealers, vessel operators, and owners to obtain supporting documentation for the correction and to ensure industry concurs with the data corrections. Given that discrepancies between VTR and dealer data are investigated and resolved, NMFS does not consider as necessary the proposed measure for observers to collect a volumetric estimate of total catch to help identify or resolve discrepancies between VTR and dealer data.
Framework 4 discusses the concern that catch is not being accurately reported, but cautions whether the proposed measure would be more accurate than methods currently used by vessel operators or dealers to estimate catch. The volumetric conversions proposed in Framework 4 are based on herring harvested in other parts of the world. Using a volumetric conversion assumes consistency in the size, weight, and density of the catch, but there can be substantial variability in the catch composition of the herring fishery, depending on the area and season. The proposed 5 percent deduction from total weight to account for water in the tanks is based on best known practices among the industry, but the Council did not rigorously evaluate the amount of the deduction. For these reasons, Framework 4 explains that converting a volume of total fish to pounds based on a herring-based conversion could produce less accurate catch estimates than current vessel or dealer estimates. Because of the potential variability and uncertainties associated with volumetric estimates and volumetric conversions, catch estimates derived under this proposed measure would not be used to replace any current estimates of herring catch. Therefore, the impact of this proposed measure on the herring resource is likely to be negligible.
Framework 4 suggests that portside samplers, in addition to observers, could provide independent catch verification in the herring fishery. Currently, the portside sampling program that samples the herring fishery is a voluntary program administered by the states of Massachusetts and Maine. It is not possible to implement a mandatory Federal data collection through a voluntary state sampling program. It may be possible to collect catch data in a future Federal portside sampling program, such as the portside sampling alternative for the midwater trawl fleet being considered in the Council's Industry-Funded Monitoring Omnibus Amendment, provided that the data collected would improve monitoring in the herring fishery.
During the development of Framework 4, NMFS expressed concern regarding the utility of the proposed measure and the reliability of a volumetric estimate of total catch. When
In summary, NMFS seeks public comment on whether and how the proposed measure has practical utility that outweighs its additional compliance and administrative costs. Specifically, NMFS seeks comment on whether and how the benefit of the information provided from this measure compares to the additional burden on vessel owner/operators to certify their fish holds and make available a measuring stick for observers, consistent with the requirements of MSA National Standards 5 and 7 and the Paperwork Reduction Act (PRA). NMFS seeks comment on the quality of the information produced and whether and how it is relevant to and sufficient for the purposes of monitoring the fishery, facilitating inseason management, or judging the performance of the management regime, consistent with the requirements of MSA National Standard 2. NMFS also seeks comment on whether and how this measure allows the fishery to operate at the lowest possible administrative and enforcement costs relative to any additional monitoring benefit provided by this measure, consistent with the requirements of MSA National Standard 5. Lastly, NMFS seeks comment on the accuracy of the burden estimate, ways to enhance the quality or utility of the information collected, and ways to minimize the burden of the information collection. After evaluating public comment, NMFS will determine if the proposed volumetric catch estimate requirement can be approved or if it must be disapproved.
Framework 4 would require fish holds of vessels with Category A or B limited access herring permits to be empty of fish before leaving the dock on any trip declared into the herring fishery. A waiver may be issued by an authorized law enforcement officer when fish have been reported as caught and cannot be sold due to the condition of fish.
The Council proposed this measure to enhance catch monitoring and discourage wasteful fishing practices in the herring fishery. The practice of discarding unmarketable fish on a subsequent trip is not known to be prevalent in the herring fishery, but some stakeholders are concerned that fish not purchased by a dealer, and discarded on a subsequent trip, may not be reported on the VTR. The Council intended this measure to discourage the discarding of unreported fish, provide a mechanism to document when harvested fish become unmarketable, and prevent vessel operators from mixing fish from multiple trips in the hold, potentially biasing catch data.
Initially, this measure consisted of only the requirement that vessel fish holds be empty of fish at the beginning of a herring trip. But recognizing that there may be unforeseen events that make it difficult to sell fish (
NMFS is concerned with the lack of justification for this measure and how the compliance and enforcement costs associated with this measure seem to outweigh the benefits. NMFS would still need to significantly develop this measure prior to implementation, including developing a protocol for checking if fish holds are empty of fish, developing guidance for when/how waivers would be issued, specifying what a vessel must do if it cannot obtain a waiver, and developing a process to use/track waivers. At the April 2014 Council meeting, NMFS commented that it was unclear how this requirement would improve catch data and urged the Council to ensure that Framework 4 provided clear rationale for this measure.
While prohibiting the disposal of unmarketable catch at sea, unless a waiver is issued, may discourage wasteful fishing practices, there is insufficient support in the record to determine whether this practice is frequently occurring in the herring fishery. The costs associated with a herring trip, such as fuel, crew wages, and insurance, are substantial, so it is unlikely that vessel owners/operators are harvesting fish with the intention to discard rather than sell the fish. Additionally, Framework 4 acknowledges that disposing of unmarketable catch at sea on a subsequent fishing trip is not known to occur regularly in the herring fishery.
Framework 4 explains that it is unclear whether unmarketable catch discarded at sea on a subsequent trip is reported. Part of the justification for the waiver provision is to provide a way to verify that fish have been reported and document the extent to which vessels are departing on trips with fish in their holds. However, the Council's proposed waiver provides no way of verifying the amount of fish reported relative to the amount of fish left in the hold. Therefore, NMFS does not consider this measure to contain a viable mechanism to verify whether harvested fish that are left in the hold were reported by the vessel.
Because the proposed measure lacks a mechanism to verify or correct the amount of fish reported on the VTR, the proposed measure is unlikely to improve catch monitoring in the herring fishery. In contrast, the compliance and enforcement costs associated with the proposed measure may be high. For example, vessel operators needing to dispose of fish at sea may lose time and money waiting for an authorized law enforcement officer to travel to their vessel, inspect it, and issue a waiver. Additionally, it would likely be time consuming for authorized officers to issue waivers and would divert resources from other law enforcement duties.
This proposed measure is also intended to enhance catch monitoring in the herring fishery by preventing vessel operators from mixing fish from multiple trips in the hold and biasing catch data. NEFOP observers sample the catch while it is on the deck, before it is placed in the fish hold, so there is no chance that observers would be sampling fish from multiple trips that were mixed in the hold. The herring fishery is also sampled portside by the Massachusetts' Department of Marine Fisheries (MA DMF) and Maine's
The Atlantic States Marine Fisheries Commission is also considering a requirement that vessel fish holds be empty of fish before vessels depart on a herring fishing trip in Amendment 3 to its Interstate FMP for Atlantic Herring. Establishing a similar provision in this action may promote coordination between Federal and state management of the herring fishery, but for the reasons described above, it is unlikely to improve catch monitoring in the herring fishery.
In summary, NMFS seeks public comment on whether and how the proposed measure has practical utility that outweighs its additional compliance and enforcement costs. Specifically, NMFS seeks comment on whether and how requiring empty fish holds improves catch monitoring and how any benefit of catch monitoring provided by requiring empty fish holds compares to the additional burden on vessel owner/operators to obtain a waiver from an authorized officer, consistent with the requirements of MSA National Standard 7 and the PRA. NMFS also seeks comment on whether and how the measure minimizes costs, avoids unnecessary duplication, and provides fishermen with the greatest possible freedom of action in conducting business or imposes an unnecessary enforcement burden relative to the requirements of MSA National Standard 7. Further, NMFS seeks comment on the proposed measure's efficient use of fishery resources, specifically whether and how this measure allows the fishery to operate at the lowest possible enforcement costs relative to the requirements of MSA National Standard 5. Lastly, NMFS seeks comment on the accuracy of the burden estimate, ways to enhance the quality or utility of the information collected, and ways to minimize the burden of the information collection. After evaluating public comment, NMFS will determine if the proposed empty fish hold requirement can be approved or if it must be disapproved.
Framework 4 proposes clarifications to slippage measures implemented in Amendment 5 (79 FR 8786, February 13, 2014). Currently, slippage requirements exist for vessels with limited access herring permits and midwater trawl vessels fishing in Groundfish Closed Areas.
Slippage is currently defined at 50 CFR 648.2 as catch that is discarded prior to it being brought aboard a vessel issued a herring permit and/or prior to making it available for sampling and inspection by a NMFS-approved observer. Slippage includes releasing catch from a codend or seine prior to the completion of pumping the catch aboard and the release of catch from a codend or seine while the codend or seine is in the water. Fish that cannot be pumped and remain in the codend or seine at the end of pumping operations are characterized as operational discards, not slippage. Discards that occur after the catch is brought on board and sorted are also not considered slippage.
Measures at § 648.11(m)(4) prohibit slippage aboard any vessel issued a limited access herring permit and carrying a NMFS-approved observer, except when safety or mechanical failure necessitate slipping catch or when excess catch of spiny dogfish prevents fish from being pumped aboard the vessel. Vessel may also make test tows without pumping catch on board for sampling, provided the gear is re-set without releasing its contents and all catch from test tows would be available to the observer to sample when the next tow is brought on board. If catch is slipped for any the reasons described previously, the vessel operator must complete and sign a Released Catch Affidavit detailing where, when, and why catch was slipped and the estimated weight of each species either retained or slipped on that tow. A completed affidavit must be submitted to NMFS within 48 hr of the end of the trip.
When midwater trawl vessels are fishing in the Groundfish Closed Areas, measures at § 648.202(b) require those vessels to carry an observer and prohibit slippage, except when slippage is due to safety, mechanical failure, or excess catch of spiny dogfish, and operational discards. Operational discards are the relatively small amounts of fish that remain in the codend or seine after catch is pumped aboard the vessel. The Groundfish Closed Areas include Closed Area I, Closed Area II, Nantucket Lightship Closed Area, Cashes Ledge Closure Area, and the Western Gulf of Maine Closure Area. Midwater trawl vessels fishing in the Groundfish Closed Areas may make test tows, but if catch is slipped or operationally discarded, the vessel must immediately exit the Groundfish Closed Areas for the remainder of that trip and complete a Released Catch Affidavit within 48 hr of the end of the trip.
When sampling catch at-sea, observers document all catch not brought on board and categorize the catch based on disposition code. Those codes are later evaluated to determine if they were discard, slippage, or operational discard events. Consistent with the recommendations of the Herring Plan Development Team, the Council believes that clarifying the treatment of catch not brought on board should enhance the effectiveness and enforceability of existing and proposed management measures to address slippage.
Framework 4 proposes to maintain the existing requirements that prohibit operational discards aboard midwater trawl vessels fishing in the Groundfish Closed Areas but allow operational discards to occur on board herring vessels fishing outside the Groundfish Closed Areas. Current observer protocols include documenting operational discards and existing regulations require vessel operators to assist the observer with this process. Because it can be time and labor intensive to bring these small amounts of fish on board the vessel, the compliance costs associated with prohibiting operational discards outside the Groundfish Closed Areas would likely outweigh any benefits to the catch monitoring program and the herring resource. Especially considering that hauls containing operational discards are considered to be “observed” hauls as the amount and composition of operational discards can be estimated by observers. For these reasons, the Council decided to maintain the existing requirements that prohibit operational discards aboard midwater trawl vessels fishing in the Groundfish Closed Areas but allow operational discards to occur on herring vessels fishing outside the Groundfish Closed Areas.
Framework 4 proposes clarifying slippage, such that a slippage event due to safety, mechanical failure, or excess catch of spiny dogfish would be categorized as an “allowable” slippage event and slippage for any other reason would be categorized as a “non-allowable” slippage event. These proposed categorizations are intended to help clarify the type of slippage event and would then be used to determine whether a vessel would be subject to any slippage consequences proposed in Framework 4.
Framework 4 proposes that catch not brought on board due to gear damage
Framework 4 proposes that catch that falls out of or off of gear and is not brought on board would not be categorized as a slippage event. In general, only small amounts of catch fall out or off of gear during fishing and/or when catch is being brought aboard the vessel, unlike the potential for catch loss due to mechanical failure. Therefore, the Council believes that fish that fall out of the gear should be categorized as discarded catch, but not slippage. For these reasons, instances of catch falling out or off of gear during fishing and/or when catch is being brought aboard the vessel would not be subject to existing slippage requirements or any proposed slippage consequences in Framework 4.
Building on the slippage restrictions established in Amendment 5, Framework 4 proposes requiring vessels to move away from the slippage location following an allowable slippage event before resuming fishing. Specifically, vessels with Category A or B herring permits slipping catch, due to safety, mechanical failure, or excess catch of spiny dogfish, would be required to move at least 15 nautical miles (27.78 km) away from the slippage event location. The vessel would be allowed to move 15 nautical miles (27.78 km) away in any direction, but it would be prohibited from resuming fishing until it was at least 15 nautical miles (27.78 km) from the location of the allowable slippage event. Additionally, the vessel would be required to remain at least 15 nautical miles (27.78 km) from the slippage event location for the duration of that fishing trip.
Framework 4 also proposes a trip termination consequence for non-allowable slippage events. Specifically, vessels with Category A or B herring permits slipping catch, for any reason other than safety, mechanical failure, or excess catch of spiny dogfish, would be required to immediately stop fishing and return to port. After having returned to port and terminated the fishing trip, vessels would be allowed to initiate another fishing trip, consistent with the existing pre-trip notification requirements (
Vessels with Category A or B limited access herring permits fishing with midwater trawl gear in the Groundfish Closed Areas would also be subject to these proposed slippage consequences. Midwater trawl vessels are currently required to exit the Groundfish Closed Areas following an allowable slippage event and remain outside the Groundfish Closed Areas for the duration of that trip. Under these proposed slippage consequences, vessels with Category A or B limited access herring permits fishing with midwater trawl gear in the Groundfish Closed Area would also be required to move at least 15 nautical miles (27.78 km) away from the slippage location following an allowable slippage event. Therefore, following an allowable slippage event, a midwater trawl vessel would need to exit the Groundfish Closed Areas and remain outside of the Groundfish Closed Areas for the remainder of the fishing trip. If the vessel has been issued a Category A or B limited access herring permit, the vessel would also be required to move at least 15 nautical miles (27.78 km) away from the slippage event and remain at least 15 nautical miles (27.78 km) away from the slippage event for the remainder of the fishing trip. Additionally, vessels with Category A or B limited access herring permits fishing with midwater trawl gear in the Groundfish Closed Areas would be required to terminate the fishing trip and return to port following a non-allowable slippage event.
The Council believes that additional consequences for both allowable and non-allowable slippage events will enhance the catch monitoring program established through Amendment 5 by further discouraging slippage in the herring fishery. The herring fishery is a relatively high-volume fishery capable of catching large quantities of fish in a single tow. Therefore, even a few slippage events have the potential to substantially affect species composition data, especially extrapolations of incidental catch. The Council recommended the requirement that vessels move at least 15 nautical miles (27.78 km) following an allowable slippage event for two reasons. First, the 15-nautical mile (27.78-km) move requirement would apply uniformly to all vessels that slipped catch, unlike other considered alternatives (
Slippage is a significant concern for many stakeholders because they believe it undermines the ability to collect unbiased estimates of herring catch, as well as other species, in the herring fishery. Stakeholders expressed support for proposed measures to address slippage in Framework 4, suggesting that implementing these measures would further ensure that there is accountability for all catch in the herring fishery. Framework 4 explains that when the benefits of slipping catch outweigh the costs of slipping catch, vessel operators are likely to slip catch. Additionally, Framework 4 describes the impact of the slippage consequence measures as low positive for the herring resource and low negative for the herring industry. Minimizing slippage events and better documentation of slipped catch may improve estimates of bycatch in the fishery. To the extent that the amount and species composition of slipped catch can be sampled and/or estimated, catch monitoring will be enhanced. To the extent that slippage events can continue to be reduced, bycatch can be further minimized.
Framework 4 proposes requiring vessels with limited access herring permits to report slippage events, including the reason for the slippage
This proposed rule also contains minor clarifications and corrections to existing regulations. NMFS proposes these adjustments under the authority of section 305(d) to the MSA, which provides that the Secretary of Commerce may promulgate regulations necessary to ensure that framework adjustments to FMPs are carried out in accordance with the FMP and the MSA. These adjustments, which are identified and described below, are necessary to clarify current regulations and would not change the intent of any regulations.
NMFS proposes to add a transiting provision for herring management areas with seasonal sub-ACLs. This provision would allow vessels to transit herring management areas during periods when zero percent of the sub-ACL for those areas was available for harvest with herring harvested from other herring management areas aboard, provided gear was stowed and not available for use. This provision was overlooked during rulemaking for Framework Adjustment 2 to the Herring FMP and is consistent with the intent of that action. NMFS proposes to remove regulations at § 648.80(d)(7) describing requirements for midwater trawl vessels fishing in Groundfish Closed Area I because they are redundant with regulations at § 648.202(b) describing requirements for midwater trawl vessels fishing in any of the Groundfish Closed Areas. NMFS proposes adding the definition of operational discards at § 648.2 and clarifying that operational discards are not permitted aboard midwater trawl vessels fishing in Groundfish Closed Areas, unless those fish have first been made available to an observer for sampling. NMFS proposes revising references to individual years in regulations for carryover at § 648.201 to more correctly describe the timing of carryover. Lastly, NMFS proposes to correct coordinates for Herring Management Area 2 at § 648.200(f)(2) to more accurately define the area.
Except for the proposed measures requiring volumetric estimates of catch and empty fish holds at the beginning of a trip and pursuant to section 304(b)(1)(A) of the MSA, the NMFS Assistant Administrator has preliminarily determined that this proposed rule is consistent with the Atlantic Herring FMP; other provisions of the MSA; and other applicable law, subject to further consideration after public comment.
This proposed rule has been determined to be not significant for purposes of Executive Order 12866.
The Council prepared an IRFA, as required by section 603 of the Regulatory Flexibility Act (RFA). The IRFA describes the economic impact this proposed rule, if adopted, would have on small entities. A summary of the analysis follows. A copy of this analysis is available from the Council or NMFS (see
This action proposes measures intended to further enhance catch monitoring and address discarding in the herring fishery. The preamble to this rule includes a complete description of the reasons why this action is being considered; therefore, those reasons are not repeated here.
This action proposes measures intended to further enhance catch monitoring and address discarding in the herring fishery. The preamble to this proposed rule includes a complete description of the objectives of and legal basis for this action; therefore, that description is not repeated here.
This action proposes measures to regulate the activity of vessels with limited access herring permits and vessels with Category A or B limited access herring permits. Therefore, the regulated entity is the business that owns at least one limited access herring permit.
In 2013, the most recent full year of fishery permit data, 93 fishing vessels were issued a limited access herring permit. Vessels and/or permits may be owned by entities affiliated by stock ownership, common management, identity of interest, contractual relationships, or economic dependency. For the purposes of this analysis, ownership entities are defined by those entities with common ownership personnel as listed on permit application documentation. Only permits with identical ownership personnel are categorized as an affiliated entity. For example, if five permits have the same seven personnel listed as co-owners on their application paperwork, those seven personnel form one ownership entity, covering those five permits. If one or several of the seven owners also own additional vessels, with sub-sets of the original seven personnel or with new co-owners, those ownership arrangements are deemed to be separate entities for the purpose of this analysis.
Based on this ownership criterion, NMFS dealer data for recent years (2010-2013), and the size standards for finfish and shellfish firms, there are 68 regulated fishing firms with a limited access herring permit. Of those 68 firms, there are 61 small entities and 7 large entities. Not all of these permitted firms are active: Only 32 small entities and 5 large entities were actively fishing for herring during the last 3 years. Additionally, there are 32 regulated fishing firms that hold Category A or B herring permits. Of those 32 firms, there are 27 small entities and 5 large entities. Not all of these permitted firms are active: Only 19 small entities and 5 large entities were actively fishing for herring during the last 3 years.
This action proposes collection-of-information requirements subject to review and approval by the Office of Management and Budget (OMB) under the PRA. This requirement will be submitted to OMB for approval under Control Numbers 0648-0202 and 0648-0674.
This action proposes that limited access vessels report slippage events via the daily VMS herring catch report. All limited access herring vessels are currently required to submit daily VMS catch reports, therefore, reporting slippage via VMS is not expected to cause any additional time or cost burden above that which was previously approved under OMB Control Number 0648-0202.
This action proposes that vessels with limited access herring permits that store herring catch in fish holds would be required to certify the capacity of their fish holds and mark their holds at regular intervals to facilitate collection of volumetric catch estimates. The fish hold capacity measurement would need to be certified by one of the following entities: (1) A Certified Marine Surveyor with a fishing specialty by the National Association of Marine Surveyors (NAMS); (2) an Accredited Marine Surveyor with a fishing specialty by the Society of Accredited Marine Surveyors
This action also proposes that vessels with Category A or B limited access herring permits would be required to have empty holds prior to departing on a herring trip. A waiver may be issued by an authorized law enforcement officer when fish have been reported as caught and cannot be sold due to the condition of fish. Forty-three vessels were issued a Category A or B limited access herring permit in 2013. Therefore, an estimated 43 vessels would be required to obtain a waiver from an authorized officer prior to leaving the dock on a herring trip with fish in the hold. The burden to the vessel operator/owner associated with obtaining a waiver would be any loss of time and/or money waiting for an authorized officer to travel to their vessel, inspect it, and issue a waiver.
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 Regional Administrator (see
Notwithstanding any other provisions of the law, no person is required to, nor shall any person be subject to a penalty for failure to comply with, a collection of information subject to the requirements of the PRA, unless that collection of information displays a currently valid OMB Control Number. All currently approved NOAA collections of information may be viewed at:
This action does not duplicate, overlap, or conflict with any other Federal law.
This action considered alternatives to the proposed action, but, according to the analysis in Framework 4, the non-selected alternatives would not have met the stated goal of the action, minimized any significant economic impact on small entities compared to the proposed action, or been consistent with applicable law.
To help minimize slippage, Framework 4 considered slippage consequence measures that would have required vessels to leave either a herring management or statistical area following an allowed slippage event and remain out of that area for the remainder of the trip. The economic cost of complying with these requirements and their effectiveness at deterring slippage would have arbitrarily depended upon the location of the slippage event and the magnitude of the required move. Therefore, the impact of the non-selected alternatives would not have applied uniformly to all vessels that slipped catch, unlike the impact of complying with the proposed action requiring vessels to move 15 nautical miles (27.78 km), and the non-selected alternatives may not minimize bycatch to the extent practicable. Framework 4 also considered only requiring trip termination following non-allowable slippage events, rather than the proposed action of requiring both a 15-nautical mile (27.78-km) move following allowable slippage events and trip termination following non-allowable slippage events. The proposed action was selected rather than just a trip termination requirement because the proposed action likely provides a greater incentive to not slip catch, thereby helping to minimize bycatch to the extent practicable.
To help identify errors with catch information in the herring fishery, Framework 4 considered requiring dealers to have vessel representatives corroborate dealer landings data and requiring VTRs and dealers reports to be submitted daily rather than weekly. The analysis in Framework 4 indicated that both these non-selected alternatives would have only had a negligible impact on improving the quality of catch information in the herring fishery. Additionally, the reporting burden associated with these non-selected alternatives would have likely been greater than the reporting burden associated with the proposed action requiring vessel fish holds to be empty of fish at the beginning of a herring trip.
Lastly, to improve the quality of herring catch information, Framework 4 considered requiring dealers to estimate herring landings based on standardized weight conversions for specific volumes of herring (
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
(a) * * *
(10) * * *
(iv) * * *
(P)
(m) * * *
(3) * * *
(ii) Reasonable assistance to enable observers to carry out their duties, including but not limited to assistance with: Obtaining and sorting samples; measuring decks, codends, and holding bins; providing an observer a NMFS-approved measuring stick when requested; estimating the volume of fish in fish hold(s) before offloading; collecting bycatch when requested by the observers; and collecting and carrying baskets of fish when requested by the observers.
(4)
(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 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 which can be pumped from the net prior to release.
(ii) Vessels may make test tows without pumping catch on board if the net is re-set without releasing its contents provided that all catch from test tows is available to the observer to sample when the next tow is brought on board for sampling.
(iii) If a vessel issued any limited access herring permit slips catch, the vessel operator must report the slippage event on the Atlantic herring daily VMS catch report and indicate the reason for slipping catch. Additionally, 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.
(iv) If a vessel issued an All Areas or Areas 2/3 Limited Access Herring permit slips catch for any of the reasons described in paragraph (m)(4)(i) of this section, the vessel operator must move at least 15 nm (27.78 km) from the location of release before deploying any gear again, and must stay at least 15 nm (27.78 km) away from the slippage event location for the remainder of the fishing trip.
(v) If catch is slipped by a vessel issued an All Areas or Areas 2/3 Limited Access Herring permit for any reason not described in paragraph (m)(4)(i) of this section, the vessel operator must immediately terminate the trip and return to port. No fishing activity may occur during the return to port.
(5) Vessels must carry on board a NMFS-approved measuring stick which must be made available to the observer upon request.
(r) * * *
(1) * * *
(ii) * * *
(D) For vessels issued an All Areas or Areas 2/3 Limited Access Herring Permit to begin a declared herring trip to fish for, possess, transfer, or receive herring without fish holds empty of fish as specified at § 648.204(c), unless the vessel has received a waiver to begin a trip with fish in the fish hold.
(vii) * * *
(F) Transit or be in an area that has zero percent sub-ACL available for harvest specified at § 648.201(d) with herring on board, unless such herring were caught in an area or areas with an available sub-ACL specified at § 648.201(d), all fishing gear is stowed and not available for immediate use as defined in § 648.2, and the vessel is issued a vessel permit that authorizes the amount of herring on board for the area where the herring was harvested.
(r) * * *
(2) * * *
(v) Fish with midwater trawl gear in any Northeast Multispecies Closed Area, as defined in § 648.81(a) through (e), without a NMFS-approved observer on board, if the vessel has been issued an Atlantic herring permit.
(vi) Slip or operationally discard catch, as defined at § 648.2, unless for one of the reasons specified at § 648.202(b)(2), if fishing any part of a tow inside the Northeast Multispecies Closed Areas, as defined at § 648.81(a) through (e).
(vii) Fail to immediately leave the Northeast Multispecies Closed Areas and comply with reporting requirements after slipping or operationally discarding catch, as required by § 648.202(b)(4).
(viii) Slip catch, as defined at § 648.2, unless for one of the reasons specified at § 648.11(m)(4)(i).
(ix) For vessels with All Areas or Areas 2/3 Limited Access Herring Permits, fail to move 15 nm (27.78 km), as required by § 648.11(m)(4)(iv) and § 648.202(b)(4)(iv).
(x) For vessels with All Areas or Areas 2/3 Limited Access Herring Permits, fail to immediately return to port, as required by § 648.11(m)(4)(v) and § 648.202(b)(4)(iv).
(xi) Fail to complete, sign, and submit a Released Catch Affidavit if fish are released pursuant to the requirements at § 648.11(m)(4)(iii).
(xii) Fail to report a slippage event on the Atlantic herring daily VMS catch report, as required by § 648.11(m)(4)(iii).
(xiii) Fail to carry on board, or make available to an observer upon request, a NMFS-approved measuring stick, as required by § 648.11(m)(5).
(f) * * *
(2)
(e) A vessel may transit an area that has zero percent sub-ACL available for harvest specified in paragraph (d) of this section with herring on board, provided such herring were caught in an area or areas with sub-ACL available specified in paragraph (d) of this section, that all fishing gear is stowed and not available for immediate use as defined in § 648.2, and the vessel is issued a permit that authorizes the amount of herring on board for the area where the herring was harvested.
(f) Up to 500 mt of the Area 1A sub-ACL shall be allocated for the fixed gear fisheries in Area 1A (weirs and stop seines) that occur west of 67°16.8′ W. long (Cutler, Maine). This set-aside shall be available for harvest by fixed gear within the specified area until November 1 of each fishing year. Any portion of this allocation that has not been utilized by November 1 shall be restored to the sub-ACL allocation for Area 1A.
(g)
(b) * * *
(2) No vessel issued an Atlantic herring permit and fishing with midwater trawl gear, when fishing any part of a midwater trawl tow in the Closed Areas, may slip or operationally discard catch, as defined at § 648.2, except in the following circumstances:
(4) If catch is slipped or operational discarded by a vessel, the vessel operator must:
(ii) Complete and sign a Released Catch Affidavit detailing: The vessel name and permit number; the VTR serial number; where, when, and for what reason the catch was released; the estimated weight of each species brought on board or released on that tow. A completed affidavit must be submitted to NMFS within 48 hr of the end of the trip.
(iii) Report slippage events on the Atlantic herring daily VMS catch report and indicate the reason for slipping catch if the vessel was issued a limited access herring permit.
(iv) Comply with the measures to address slippage specified in § 648.11(m)(4)(iv) and (v) if the vessel was issued an All Areas or Areas 2/3 Limited Access Herring Permit.
(c) Vessels issued an All Areas or Areas 2/3 Limited Access Herring Permit must have fish holds empty of fish before leaving the dock on any trip declared into the Atlantic herring fishery. After inspection by an authorized officer, a waiver for the requirement to have fish holds empty of fish may be issued to vessels for instances when there are fish in the hold due to a lack of marketability or refrigeration malfunction, provided those fish have been reported by the vessel.
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Proposed rule; request for comments.
This proposed rule, if adopted, would clarify the regulatory requirements for vessels using midwater trawl gear in the Pacific Coast Groundfish Fishery Shorebased Individual Fishing Quota Program. This action is needed to eliminate inconsistencies and confusion in the current regulations. For vessels targeting Pacific whiting, the action would clarify that the retention of prohibited and protected species is allowed until landing. The disposition of prohibited and protected species would be specified consistent with the Pacific Coast Groundfish Fishery Management Plan, the Pacific Coast Salmon Fishery Management Plan, and other applicable law.
Comments on this proposed rule or the Environmental Assessment (EA) supporting the action must be received no later than 5 p.m., local time on September 28, 2015.
You may submit comments on this document, identified by NOAA-NMFS-2015-0093, by any of the following methods:
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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 William W. Stelle Jr., Regional Administrator, West Coast Region NMFS, 7600 Sand Point Way NE., Seattle, WA 98115-0070 and to OMB by email to
This action would amend the Pacific Coast groundfish fishery regulations to eliminate redundancies and inconsistencies relative to the use of midwater trawl gear in the Shorebased Individual Fishing Quota Program (Shorebased IFQ Program). The action is consistent with policy decisions that the Pacific Fishery Management Council (Council) made during the implementation of Amendment 20 to the Pacific Coast Groundfish Fishery Management Plan (groundfish FMP).
In 2011, a trawl catch share program was implemented under Amendment 20 to the groundfish FMP. The trawl catch share program included the Shorebased IFQ Program, where individual permit holders receive quota pounds (QP) that they can fish for, lease, or sell. Permit holders also receive QP to cover catch of Pacific Halibut.
In anticipation of the trawl catch share program, the groundfish regulations were restructured on October 1, 2010 (75 FR 60868). When the Shorebased IFQ Program was implemented, the midwater Pacific whiting shorebased fishery and the bottom trawl fishery were merged to create a single Shorebased IFQ fishery. Many of the pre-IFQ fishery management measures relating to time and area management were retained in the regulations for use in the Shorebased IFQ Program. However, integrating pre-IFQ regulations with new regulations for the Shorebased IFQ Program resulted in inconsistencies and numerous unclear and confusing management restrictions relative to the use of midwater trawl gear.
Groundfish fishery management includes the use of time and area restrictions. Time and area restrictions affecting the use of midwater trawl gear include: Trawl Rockfish Conservation Areas, Pacific whiting primary seasons, Ocean Salmon Conservation Zones (OSCZs), Bycatch Reduction Areas (BRAs), and Klamath and Columbia River salmon conservation zones. In addition, there are midwater trawl trip limit restrictions for operating shoreward of the 100 fathom (fm) contour in the Eureka area, and a prohibition on night fishing south of 42° north latitude.
Vessel monitoring systems (VMSs) that automatically transmit hourly position reports to NMFS Office of Law Enforcement (OLE) are the primary management tool used to monitor vessel compliance with time and area restrictions. All vessels in the Shorebased IFQ Program are required to have an operational VMS. In addition, each vessel operator is required to submit a declaration report to OLE that allows the vessel's position to be linked to the type of fishing gear being used. In some cases, the declaration also identifies the particular species the vessel is fishing for and the target strategy. For the Shorebased IFQ Program, vessels using midwater trawl may declare either “limited entry midwater trawl, non-whiting shorebased IFQ” or “limited entry midwater trawl, Pacific whiting shorebased IFQ.”
Midwater trawl gear has primarily been used to target Pacific whiting, but can also be used to target other groundfish species. Prior to 2002, when widow rockfish was declared overfished, midwater trawl was used to target widow rockfish, yellowtail rockfish, and, to a lesser extent, chilipepper rockfish. During the rebuilding period for widow rockfish, the access to co-occurring species was constrained by the low widow rockfish Annual Catch Limits (ACLs). Since widow rockfish was declared rebuilt in 2012, there has been increased interest in targeting non-whiting groundfish with midwater trawl gear, particularly in the management area north of 40°10′ north latitude. Since 2011, midwater trawl gear has been used to target Pacific whiting and non-whiting north of 40°10′ north latitude by vessels in the Shorebased IFQ Program. South of 40°10′ north latitude midwater trawling has been allowed year round seaward of the trawl RCAs for all target species.
Groundfish management includes restrictions on the retention of certain non-groundfish species, including prohibited and protected species. Prohibited species include all salmonids, Pacific halibut, and Dungeness crab off Oregon and Washington. Protected species include
From 2007 through 2010, prior to the Shorebased IFQ Program, the Pacific whiting shorebased fishery was composed of vessels landing 10,000 pounds or more of Pacific whiting on a trip and was managed under exempted fishing permits (EFPs). The terms and conditions of the EFPs established “maximized retention” provisions where only species longer than 6 feet and minor amounts of operational discards were allowed to be discarded. The EFPs allowed vessels to land catch containing prohibited and protected species. The EFPs issued to first receivers specified handling and disposition measures for prohibited species. In 2011, with implementation of the Shorebased IFQ Program, a maximized retention provision was added to the groundfish regulations. However, the provision did not address the retention of prohibited species other than Pacific halibut, nor did it establish handling and disposition requirements for prohibited species. For consistency with the salmon FMP and Pacific halibut regulations, provisions for the retention and disposition of prohibited species would be added by this rule.
Protected species are species protected under the ESA, the Marine Mammal Protection Act, the Migratory Bird Treaty Act, and Executive Order 13186. A December 2012, section 7 biological opinion for the groundfish fishery included reasonable and prudent measures that require the collection of important biological data on specific protected species. The West Coast Groundfish Observer Program (WCGOP) has sampling protocols for sampling discards at-sea that includes the collection of biological data on marine mammals, seabirds, turtles, eulachon, and green sturgeon. However, protected species in maximized retention landings are not sampled by observers. Therefore, regulatory revisions are necessary to assure that valuable biological data are gathered.
As noted above, the following changes are intended to revise the regulations consistent with previous actions taken by the Council to implement Amendment 20. This action is needed to eliminate inconsistencies and confusion in the current regulations.
The proposed regulations would revise the definition of Pacific whiting trip consistent with Appendix E of the groundfish FMP, which details the Final Preferred Alternative adopted under Amendment 20, and which is consistent with the Environmental Impact Statement analysis conducted in support Amendment 20. Appendix E defines non-whiting landings as those with less than 50 percent Pacific whiting by weight. Therefore, this proposed rule would define landings with 50 percent or more Pacific whiting by weight as Pacific whiting shorebased IFQ trips.
The current regulations do not have a minimum threshold for the amount of Pacific whiting that must be harvested on a Pacific whiting shorebased IFQ trip. Without a minimum threshold, vessels fishing north of 40°10′ north latitude have been making Pacific whiting shorebased IFQ declarations while targeting both Pacific whiting and non-whiting groundfish. The groundfish regulations include mitigation measures to reduce the take of Chinook salmon that are specific to the targeting of Pacific whiting and that are in some cases contrary to fishing practices for non-whiting species (
General definitions at 50 CFR 660.11 would be revised to add a definition for protected species. Adding the definition allows the term to be clearly used relative to the handling and disposition requirements established in the regulations. General prohibitions at 50 CFR 660.12 would be revised to prohibit the retention of protected species except as allowed for vessels on maximized retention trips. In 50 CFR 660.12 and 660.55, pre-IFQ terminology would be revised consistent with the terms established under the IFQ program.
Regulations pertaining to automatic actions in the specification and management measures provision at 50 CFR 660.60 would be updated by this action. Paragraph (c)(3)(i) of § 660.60 would be revised for readability and to clarify how BRAs may be implemented. Pre-IFQ terminology for the Pacific whiting fishery sectors would be revised consistent with the terms established under the IFQ program; an inactive Internet link would be replaced with an active link; an automatic action currently specified in regulation at 50 CFR 660.150(h)(2) would be added to the list of allowed automatic actions; and language would be added to clarify where the effective date for automatic actions is specified. These actions are being taken for consistency between the different subparts of groundfish regulations.
Regulations at 50 CFR 660.60 would be revised to add an allowance for prohibited species retention until landing on maximized retention trips in the Pacific whiting Shorebased IFQ Program. Appendix E of the groundfish FMP indicates that maximized retention is an option for Pacific whiting shorebased IFQ vessels and that Pacific halibut may be retained until landing. The Council originally considered maximized retention for the Shorebased IFQ Program at its June 2008 meeting as elements of the tracking, monitoring, and enforcement structure for ongoing management. In 2008, a maximized retention program had been recommended by the Council for implementation in Amendment 10 to the groundfish FMP prior to the start of an IFQ program. The implementing regulations for Amendment 10 included maximized retention requirements and video monitoring for vessels targeting Pacific whiting in the Pacific whiting shorebased fishery. Because Amendment 20 required full observer coverage and did not provide for video monitoring, the Amendment 10 regulations were never implemented. In late 2010, during the final stages of
This proposed rule would revise the language explaining the purpose and scope of subpart D at 50 CFR 660.100 for clarity. The regulations at 50 CFR 660.111 contain the trawl definitions. The proposed rule would revise the definitions for Catcher/Processor Coop Program, Mothership Coop Program, Pacific whiting IFQ fishery, Pacific whiting IFQ trip, and Shorebased IFQ Program for clarity. The term Pacific whiting IFQ trip would specify that a qualifying trip must be 50 percent or more Pacific whiting by weight. New definitions for maximized retention and Pacific whiting fishery are being added for clarity.
The trawl fishery prohibitions at 50 CFR 660.112 would be revised to clearly prohibit first receivers from disposing of prohibited and protected species without sorting them from maximized retention landings and to clearly state that all midwater trawl is prohibited outside the Pacific whiting primary season north of 40°10′ north latitude. Redundant regulatory text at 50 CFR 660.112(b)(2)(ii) would be removed. Duplicate language pertaining to the weighing of catch, which is also stated in regulations at 50 CFR 660.130(d), would be removed and only sorting provisions would be retained.
Numerous minor changes would be made throughout the regulations at 50 CFR 660.130 to align the regulations with the terms defined at 50 CFR 660.11 and 660.111 and to revise pre-IFQ terminology to be consistent with the terms established under trawl rationalization. Currently, regulations at 50 CFR 660.130(c)(3) pertain to the use of midwater trawl gear both north and south of 40°10′ north latitude. This rule would add language to clearly state that midwater trawl gear is required for vessels targeting Pacific whiting during the primary seasons north of 40°10′ north latitude, and that midwater trawl gear is allowed for vessel targeting non-whiting species during the Pacific whiting Shorebased IFQ Program primary season. The action would remove a restriction that allows midwater trawl to only be used by vessels participating in the Pacific whiting Shorebased IFQ fishery that is stated at 50 CFR 660.130(c)(3) and repeated at 50 CFR 660.130(c)(4)(i)(F). These changes would allow vessels using midwater trawl gear north of 40°10′ north latitude to declare either “limited entry midwater trawl, non-whiting shorebased IFQ” or “limited entry midwater trawl, Pacific whiting shorebased IFQ” consistent with the target strategy.
North of 40°10′ north latitude vessels are allowed to carry multiple types of midwater gear, but may only declare one target strategy (whiting or non-whiting) on a trip. The regulations at 50 CFR 660.130(c)(4) would be revised for clarity. Because all midwater trawl gears have similar closed area restrictions, carrying multiple types of midwater trawl gear is not expected to affect enforcement of the closed areas. The fishery restriction at 50 CFR 660.130(c)(4)(i)(F) that only allows midwater trawl gear to be used in the Pacific whiting fishery would be removed.
The proposed rule would remove redundant regulatory text at 50 CFR 660.130(d)(i). Duplicate language pertaining to the sorting of catch, which is the same requirement stated in regulations at 50 CFR 660.112(b)(2)(ii), would be removed. Because the paragraph addresses the weighing of catch, language specific to weighing would be retained. Regulations pertaining to catch weighing requirements for Pacific whiting IFQ trips at 50 CFR 660.140(j)(2) would be consolidated and revised for clarity.
The regulations at 50 CFR 660.130(e)(4)(i) would be revised to clearly state that vessels using midwater trawl gear, regardless of the target species, are exempt from the trawl RCA restrictions in the area north of 40°10′ north latitude during the dates of the Pacific whiting primary season. This allowance already exists under the current regulations, but is confusing because the regulations may be interpreted as requiring that vessels must declare “limited entry midwater trawl, Pacific whiting shorebased IFQ” regardless of the target species. Adding clarity to the regulations and allowing either midwater trawl declaration is expected to reduce confusion for members of industry.
Regulatory language at 50 CFR 660.131(a) and (b) would be revised to remove pre-IFQ terminology for the Pacific whiting sectors, consistent with the terms established under trawl rationalization. The regulations specific to the BRAs would be moved. Trip limit restrictions for midwater trawl seaward of the 100 fm depth contour in the Eureka area are currently found at 50 CFR 660.131(d). For consistency with the other sections of the regulations, the requirement to use the 100 fm line shown on NOAA charts would be replaced with a requirement to use the 100 fm depth contour defined in groundfish regulations at 50 CFR 660.73.
Regulations pertaining to the disposition of prohibited species would be added to the Shorebased IFQ Program regulations at 50 CFR 660.140(g). For vessels on Pacific whiting IFQ trips engaged in maximized retention, clearly stating handling and disposition requirements for prohibited species and protected species would allow for accurate monitoring; would reduce incentives for increased bycatch by clearly stating that protected and prohibited species must not reach commercial markets; and would identify a preference for catch to be handled in a manner that preserves the quality for human consumption for donation to a local food share or other appropriate charitable organizations. The disposition of salmon would be consistent with salmon FMP. The disposition of Pacific halibut and Dungeness crab would be consistent with Pacific halibut regulations and state regulations.
Regulatory language at 50 CFR 660.140(b) is revised for clarity and duplicate language is removed. Retention requirements specified at 50 CFR 660.140(g) are revised such that the maximized retention requirements are clearly stated. New provisions are added at 50 CFR 660.140(g) relative to the disposition of prohibited species and protected species in maximized retention landings. First receivers that accept maximized retention landings would be responsible for following the handling and disposition protocols and for maintaining records of the disposition. Under EFPs, the vessels abandoned prohibited species to the state of landing, and each state had agreements with the first receivers and coordinated the donation or disposal of the prohibited species. The states no longer have resources to coordinate such activity. Under the IFQ program, first receivers are licensed to process IFQ catch. It is therefore reasonable for each first receiver who accepts maximized retention landings to be responsible for the disposition of the prohibited and protected species.
NMFS has made a preliminary determination that the proposed action
An environmental assessment (EA) was prepared for this action. The EA includes socio-economic information that was used to prepare the RIR and IRFA. The EA is available on the Council's Web site at
The Office of Management and Budget has determined that this proposed rule is not significant for purposes of Executive Order 12866.
An initial regulatory flexibility analysis (IRFA) was prepared, as required by section 603 of the Regulatory Flexibility Act (RFA). The IRFA 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 at the beginning of this section in the preamble and in the
NMFS is issuing this proposed rule to modify midwater trawl restrictions for vessels participating in the Shorebased IFQ Program under the authority of the groundfish FMP and the Magnuson-Stevens Act. The proposed rule would amend the regulations to remove redundancies and inconsistencies relative to the use of midwater trawl gear, and would add provisions to fully implement “maximized retention” allowances for vessels targeting Pacific whiting. Maximized retention encourages full retention of all catch while recognizing that minor discard events may occur. Two alternatives, each with sub-options, are being considered.
• North of 40°10′ north latitude midwater trawl gear may be used by vessels with a “Limited entry midwater trawl, Pacific whiting shorebased IFQ” declaration after the start of the primary season. Vessels may use midwater trawl gear to target Pacific whiting and non-whiting if the vessel also fishes in the Pacific whiting fishery.
• There is no requirement to target or land Pacific whiting on a Pacific whiting IFQ trip.
• Vessels with a “Limited entry midwater trawl, Pacific whiting shorebased IFQ” declaration may fish within the RCAs after the start of the primary season.
• Other than Pacific Halibut, prohibited species and protected species retention until landing is prohibited.
• Vessels North of 40°10′ north latitude may carry multiple types of midwater gear and both whiting and non-whiting target strategies are allowed on the same trip, however the vessel must have a valid “Limited entry midwater trawl, Pacific whiting shorebased IFQ” declaration.
• Midwater trawl gear will be allowed for all target species with a valid declaration for either “limited entry midwater trawl, non-whiting shorebased IFQ” or “limited entry midwater trawl, Pacific whiting shorebased IFQ.” Non-whiting vessels would not be obligated to also target Pacific whiting.
• A Pacific whiting IFQ trip must be 50 percent or more whiting by weight at landing.
• Midwater trawl gear will be allowed within the trawl RCAs and EFH conservation areas for all target species.
• For vessels targeting Pacific whiting on “maximized retention” trips, prohibited and protected species must be retained until landing.
• The disposition of salmon would be specified such that it is consistent with salmon FMP.
• The disposition of Pacific halibut and Dungeness crab would be specified so they are consistent with Pacific halibut regulations and state regulations.
• The disposition of protected species would be consistent with the current biological opinions.
• North of 40°10′ north latitude, vessels will be allowed to carry multiple types of midwater gear, but:
Under No Action, it is unclear whether vessels using midwater trawl north of 40°10′ north latitude must submit a declaration for “limited entry midwater trawl, Pacific whiting shorebased IFQ” even if they intend to target non-whiting species. Alternative 2 results in a low positive impact over No Action as it removes the prohibition that restricts midwater trawl to the Pacific whiting fishery north of 40°10′ north latitude and allows for the use of either midwater trawl declaration. Alternative 2 would improve tracking of activity relative to time/area restrictions and the specific target strategy. Aligning the declaration with the activity could allow for a more surgical management response that can be clearly understood by harvesters.
Under No Action, Pacific whiting trips would not be defined. Alternative 2 establishes criteria for a Pacific whiting trip as being landings that are 50 percent or more Pacific whiting by weight at landing. Alternative 2 is not expected to have a measureable effect on the vast majority of midwater trawl trips targeting Pacific whiting. Only a small number of vessels may have
Time/Area restrictions under No Action include Rockfish Conservation Areas (RCAs), Klamath River conservation zone, Columbia River conservation zone, Ocean Salmon Conservation Zones (OSCZs), Bycatch Reduction Areas (BRAs), the Eureka area 100 fm restriction, prohibition on night fishing south of 42°00′ north latitude and the Pacific whiting primary seasons. These restrictions were initially implemented to reduce incidental catch of Chinook salmon in the Pacific whiting fisheries. The Klamath River conservation zone, Columbia River conservation zone, OSCZs, and the prohibition on night fishing are specific to the targeting of Pacific whiting and would remain linked to the targeting of whiting under both No Action and Alternative 2. The impacts of No Action on the closed areas are neutral as no changes would be made to reduce the confusion by fishermen or enforcement about prohibited or allowed activities. Because widow rockfish were historically targeted at night with low bycatch, Alternative 2 revisions would clearly state that the prohibition on night fishing does not apply to non-whiting targeting. BRAs have evolved since their initial implementation in 2007 when they applied specifically to the targeting of whiting. Since 2013, the BRAs have been considered as a tool for use in the Pacific whiting sectors (all midwater trawl). Alternative 2 revisions would clearly state that the BRAs and RCA exemptions apply to all midwater trawl. Providing clarification on how time/area restrictions relate to specific target fishing activity under Alternative 2 is expected to reduce regulatory complexity and eliminate contradictory regulations. Changes under Alternative 2 are expected to be beneficial to the harvesters, managers, and enforcement.
Maximized retention is allowed under No Action. However, supporting regulations would not be added to reduce confusion regarding the landing of maximized retention catch for non-whiting target strategies. Provisions would not be added to allow the retention of prohibited species under No Action. The socio-economic impacts of managing under No Action are neutral, providing restrictions on the retention of prohibited species continue to be unenforced. Alternative 2 would revise the regulations to clearly state that maximized retention would only be allowed for trips targeting Pacific whiting, consistent with the provisions of Amendment 20. Because of relatively low bycatch by vessels targeting Pacific whiting, maximized retention allows sorting to be delayed until landing. Because whiting flesh deteriorates rapidly once the fish are caught, whiting must be minimally handled and immediately chilled to maintain the flesh quality. Allowing Pacific whiting shoreside vessels to retain unsorted catch benefits harvesters by enabling whiting quality to be maintained. Under Alternative 2, provisions would be added to allow Pacific whiting vessels to retain otherwise prohibited species until landing. Non-whiting vessels would have to continue to sort prohibited and protected species at sea. Some non-whiting landings under maximized retention have had a greater variety in bycatch than is typically seen in Pacific whiting landings and have been landed at first receivers with only one catch monitor. Long offloads associated with sorting and weighing non-whiting maximized retention catch has resulted in offload time exceeding the catch monitor's allowed work hours in a 24 hour period. Alternative 2 would also provide clarification on the disposition of protected species for maximized retention landings. Revisions to the maximized retention requirements under Alternative 2 are expected to reduce regulatory complexity and eliminate contradictory regulations, benefiting harvesters.
Under No Action, Pacific whiting trips would continue to be undefined and no protocols for handling or disposing of prohibited or protected species would be defined. The impacts of No Action are neutral, as first receivers would use current methods to identify maximized retention deliveries and determine how to handle and dispose of prohibited and protected species. Defining Pacific whiting trips under Alternative 2 should make it easier for first receivers/processors to identify which trips are classified as “maximized retention” such that it would be more clear which groundfish regulations apply. Alternative 2 specifies handling and disposition of prohibited and protected species. Clear protocols for the disposition of prohibited catch should reduce complexity and confusion for first receivers/processors. Currently, provisions that affect the disposition of prohibited or protected species exist in various federal regulations, non-groundfish FMPs, and ESA biological opinions. Clarifying these provisions in the groundfish regulations would reduce complexity in the requirements for disposition and handling of maximized retention catch and result in a low positive benefit to first receivers/processors. First receivers are currently taking salmon and grinding and processing the fish into fish meal and/or providing edible fish to food pantries, soup kitchens, or other non-profit organizations. In some states, state agencies have assisted in the transfer of fish to food banks, but this assistance is being withdrawn. However, NMFS concludes that these new regulations do not impose any significant burden on first receivers as they are consistent with current first receiver practices and with prior practices established under the 2007-2010 whiting EFPs.
This action would clarify the regulatory requirements for vessels using midwater trawl gear in the Pacific Coast Groundfish Fishery Shorebased Individual Fishery Quota Program. This action is needed to eliminate inconsistencies and confusion in the current regulations. For vessels targeting Pacific whiting, the action would clarify that the retention of prohibited and protected species is allowed until landing. The disposition of prohibited and protected species would be specified consistent with the Pacific Coast Groundfish Fishery Management Plan, the Pacific Coast Salmon Fishery Management Plan and other applicable law. As this rule is about clarifying the regulations, we do not believe that this rule will have a significant impact when comparing small versus large businesses in terms of disproportionality and profitability given available information. Nonetheless, NMFS has prepared this IRFA. Through the rulemaking process associated with this action, we are requesting comments on this conclusion.
This proposed rule contains a collection-of-information requirement subject to review and approval by OMB under the Paperwork Reduction Act (PRA). This requirement has been submitted to OMB for approval as revisions to OMB collection 0648-0619. Relative to OMB collection 0648-0619 the public reporting burden for first receivers to retain records showing the disposition of prohibited and protected
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 (enter office name) at the
Notwithstanding any other provision of the law, no person is required to respond to, and no person shall be subject to penalty for failure to comply with, a collection of information subject to the requirements of the PRA, unless that collection of information displays a currently valid OMB control number.
Pursuant to Executive Order 13175, this proposed rule eliminated redundancies and inconsistencies with state law relative to the use of midwater trawl gear and does not have a direct effect on tribes. The action is consistent with policy decisions that the Council made during the implementation of Amendment 20 to the Pacific Coast Groundfish Fishery Management Plan which was developed after meaningful consultation and collaboration with tribal officials from the area covered by the groundfish FMP. Under the Magnuson-Stevens Act at 16 U.S.C. 1852(b)(5), one of the voting members of the Pacific Council must be a representative of an Indian tribe with federally recognized fishing rights from the area of the Council's jurisdiction. The proposed regulations do not have a direct effect on the tribes.
Fisheries, Fishing, and Indian fisheries.
For the reasons set out in the preamble, 50 CFR part 660 is proposed to be amended as follows:
16 U.S.C. 1801
(a) * * *
(1) Retain any prohibited or protected species caught by means of fishing gear authorized under this subpart, unless otherwise authorized. Except as otherwise authorized, prohibited and protected species must be returned to the sea as soon as practicable with a minimum of injury when caught and brought on board.
(10) Transfer fish to another vessel at sea unless the vessel transferring fish is participating in the MS Coop or C/P Coop Programs.
(11) Fail to remove all fish from the vessel at landing (defined in § 660.11) and prior to beginning a new fishing trip, except for processing vessels participating in the MS Coop or C/P Coop Programs.
(c) * * *
(1) * * *
(i) * * *
(A)
(B)
(C)
(c) * * *
(3) * * *
(i)
(d)
(1) Automatic actions are used to:
(i) Close the MS or C/P sector when that sector's Pacific whiting allocation is reached, or is projected to be reached. The MS sector non-coop fishery may be closed by automatic action when the Pacific whiting or non-whiting allocation to the non-coop fishery has been reached or is projected to be reached.
(ii) Close one or both MS and C/P sectors when a non-whiting groundfish species with allocations is reached or projected to be reached.
(iii) Reapportion unused allocations of non-whiting groundfish species between the MS and C/P sectors.
(iv) Reapportion the unused portion of the tribal allocation of Pacific whiting to the MS sector, C/P sector, and Shorebased IFQ sector.
(v) Implement the Ocean Salmon Conservation Zone, described at § 660.131, when NMFS projects the Pacific whiting fishery and the tribal whiting fishery combined will take in excess of 11,000 Chinook within a calendar year.
(vi) Implement BRAs, described at § 660.131, when NMFS projects a sector-specific allocation will be reached before the sector's whiting allocation.
(2) Automatic actions are effective when actual notice is sent by NMFS identifying the effective time and date. Actual notice to fishers and processors will be by email, Internet
(e) [Reserved]
This subpart applies to the Pacific coast groundfish limited entry trawl fishery. * * *
(a) * * *
(2)
(i) Fail to sort, retain, discard, or dispose of catch consistent with the requirements specified at §§ 660.130(d), 660.140 (b)(2)(iii) and (viii), 660.140(g), and 660.140(j)(2).
(ii) Fail to sort, retain, discard, or dispose of prohibited and protected species from maximized retention landings consistent with the requirements specified at § 660.140(g)(3).
(iii) Retain for personal use or allow to reach commercial markets any part of any prohibited or protected species.
(b) * * *
(1) * * *
(viii) Fish on a Pacific whiting IFQ trip with a gear other than midwater groundfish trawl gear.
(ix) Fish on a Pacific whiting IFQ trip without a valid declaration for limited entry midwater trawl, Pacific whiting shorebased IFQ.
(x) Use midwater groundfish trawl gear Pacific whiting IFQ fishery primary season dates as specified at § 660.131(b).
(2) * * *
(ii) Fail to sort or dispose of catch received from an IFQ trip in accordance with the requirements of §§ 660.130(d) and 660.140(g)(3).
(a)
(c) * * *
(3)
(i) North of 40°10′ N. lat., midwater groundfish trawl gear is required for Pacific whiting fishery vessels; midwater groundfish trawl gear is allowed for vessels targeting non-whiting species during the Pacific whiting primary season for the Pacific whiting IFQ fishery. Also see restrictions on the use of midwater groundfish trawl gear within the RCAs north of 40°10′ N. lat. at § 660.130(e)(4)(i).
(ii) South of 40°10′ N. lat., midwater groundfish trawl gear is prohibited shoreward of the RCA boundaries and permitted seaward of the RCA boundaries.
(4) * * *
(i) * * *
(A) A vessel may not have both groundfish trawl gear and non-groundfish trawl gear onboard simultaneously. A vessel may not have both bottom groundfish trawl gear and midwater groundfish trawl gear onboard simultaneously. A vessel may have more than one type of limited entry bottom trawl gear on board, either simultaneously or successively, during a cumulative limit period. A vessel may have more than one type of midwater groundfish trawl gear on board, either simultaneously or successively, during a cumulative limit period.
(B) If a vessel fishes exclusively with large or small footrope trawl gear during an entire cumulative limit period, the vessel is subject to the small or large footrope trawl gear cumulative limits and that vessel must fish seaward of the RCA boundaries during that limit period.
(C) If a vessel fishes exclusively with selective flatfish trawl gear during an entire cumulative limit period, then the vessel is subject to the selective flatfish trawl gear-cumulative limits during that limit period, regardless of whether the vessel is fishing shoreward or seaward of the RCA boundaries.
(D) If more than one type of bottom groundfish trawl gear (selective flatfish, large footrope, or small footrope) is on board, either simultaneously or successively, at any time during a cumulative limit period, then the most restrictive cumulative limit associated with the bottom groundfish trawl gear on board during that cumulative limit period applies for the entire cumulative limit period, regardless of whether the vessel is fishing shoreward or seaward of the RCA.
(E) If a vessel fishes both north and south of 40°10′ N. lat. with any type of small footrope gear onboard the vessel at any time during the cumulative limit period, the most restrictive trip limit associated with the gear on board applies for that trip and will count toward the cumulative trip limit for that gear (See crossover provisions at § 660.120.)
(d) * * *
(2) * * *
(i)
(3)
(i) Processing vessels in the MS and C/P Coop Programs may use a bulk weighing scale in compliance with the equipment requirement at § 660.15(b) to derive an accurate total catch weight prior to sorting. Immediately following weighing of the total catch, the catch must be sorted to the species groups specified in paragraph (d)(1) of this section and all catch of-groundfish and non-groundfish species must be accurately accounted for and the weight of all catch other than a single predominant species deducted from the total catch weight to derive the weight of a single predominant species.
(ii) If sorting occurs on a catcher vessel in the MS Coop Program, the catch must not be discarded from the vessel and the vessel must not mix catch from hauls until the observer has sampled the catch.
(e)
(4) * * *
(i) Operating a vessel with groundfish trawl gear onboard within a trawl RCA is prohibited, except for the purpose of continuous transit, or under the following conditions when the vessel has a valid declaration for the allowed fishing:
(A) Midwater groundfish trawl gear may be used within the RCAs north of 40°10′ N. lat. by vessels targeting Pacific whiting or non-whiting during the applicable Pacific whiting primary season.
(B) Vessels fishing with demersal seine gear between 38° N. lat. and 36° N. lat. shoreward of a boundary line approximating the 100 fm (183 m) depth contour as defined at § 660.73, subpart C, may have groundfish trawl gear onboard.
(ii) Trawl vessels may transit through an applicable GCA, with or without groundfish on board, provided all groundfish trawl gear is stowed either: Below deck; or if the gear cannot readily be moved, in a secured and covered manner, detached from all towing lines, so that it is rendered unusable for fishing; or remaining on deck uncovered if the trawl doors are hung from their stanchions and the net is disconnected from the doors. These restrictions do not apply to vessels allowed to fish within the trawl RCA under paragraph (e)(4)(i) of this section.
(6)
(7)
(a)
(b)
(1)
(i) For the Pacific whiting IFQ fishery, the primary season is the period(s) of the large-scale Pacific whiting target fishery conducted after the primary season start date.
(ii) For the C/P sector, the primary season is the period(s) when catching and at-sea processing are allowed (after the season closes, at-sea processing of any fish already on board the processing vessel is allowed to continue).
(iii) For vessels delivering to motherships, the primary season is the period(s) when catching and at-sea processing is allowed for the MS sector (after the season closes, at-sea processing of any fish already on board the processing vessel is allowed to continue).
(2)
(i)
(ii)
(iii)
(3)
(i) * * *
(ii) If a vessel on a Pacific whiting IFQ trip harvests a groundfish species other than whiting for which there is a midwater trip limit, then that vessel may also harvest up to another footrope-specific limit for that species during any cumulative limit period that overlaps the start or close of the primary season.
(c)
(4)
(d)
(h) * * *
(2) The reapportionment of surplus whiting will be made by actual notice under the automatic action authority provided at § 660.60(d)(1).
(a)
(b) * * *
(2) * * *
(i) Ensure that all catch removed from a vessel making an IFQ delivery is weighed on a scale or scales meeting the requirements described in § 660.15(c).
(ii) Ensure that all catch is landed, sorted, and weighed in accordance with a valid catch monitoring plan as described in § 660.140(f)(3)(iii).
(iii) Ensure that all catch is sorted, prior to first weighing, as specified at § 660.130(d) and consistent with § 660.140(j)(2)(viii).
(g)
(1)
(2)
(3)
(i)
(A) Any prohibited species landed at first receivers must not be transferred, processed, or mixed with another landing until the catch monitor has: Recorded the number and weight of salmon by species; inspected all prohibited species for tags or marks; and, collected biological data, specimens, and genetic samples.
(B) No part of any prohibited species may be retained for personal use by a vessel owner or crew member, or by a first receiver or processing crew member. No part of any prohibited species may be allowed to reach commercial markets.
(C) Prohibited species suitable for human consumption at landing must be handled and stored to preserve the quality. Priority in disposition must be given to the donation to surplus food collection and distribution system operated and established to assist in bringing donated food to nonprofit charitable organizations and individuals for the purpose of reducing hunger and meeting nutritional needs.
(D) The first receiver must report all prohibited species landings on the electronic fish ticket and is responsible for maintaining records verifying the disposition of prohibited species. Records on catch disposition may include, but are not limited to: Receipts from charitable organizations that include the organization's name and amount of catch donated; cargo manifests setting forth the origin, weight, and destination of all prohibited species; or disposal receipts identifying the recipient organization and amount disposed. Any such records must be maintained for a period not less than three years after the date of disposal and such records must be provided to OLE upon request.
(ii)
(A)
(B)
(j) * * *
(2) * * *
(viii)
(A) The unsorted catch is weighed on a bulk weighing scale in compliance with equipment requirements at § 660.15(c);
(B) All catch (groundfish and non-groundfish species) in the landing other than the single predominant species is reweighed on a scale in compliance with equipment requirements at § 660.15(c) and the reweighed catch is deducted from the total weight of the landing;
(C) The catch is sorted to the species groups specified at § 660.130(d) prior to processing or transport away from the point of landing; and
(D) Prohibited species are sorted by species, counted, and weighed.
(a) In addition to the general prohibitions specified in § 600.725 of this chapter, it is unlawful for any person to do any of the following, except as otherwise authorized under this part:
The Department of Agriculture has submitted the following information collection requirement(s) to OMB for review and clearance under the Paperwork Reduction Act of 1995, Public Law 104-13. 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 and other forms of information technology.
Comments regarding this information collection received by September 28, 2015 will be considered. Written comments should be addressed to: Desk Officer for Agriculture, Office of Information and Regulatory Affairs, Office of Management and Budget (OMB), New Executive Office Building, 725 17th Street NW., Washington, DC 20503. Commentors are encouraged to submit their comments to OMB via email to:
An agency 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.
Forest Service, USDA.
Notice of meeting.
The Sanders Resource Advisory Committee (RAC) will meet in Thompson Falls, Montana. The committee is authorized under the Secure Rural Schools and Community Self-Determination Act (the Act) and operates in compliance with the Federal Advisory Committee Act. The purpose of the committee is to improve collaborative relationships and to provide advice and recommendations to the Forest Service concerning projects and funding consistent with Title II of the Act. Additional RAC information, including the meeting agenda and the meeting summary/minutes can be found at the following Web site:
The meeting will be held September 24, 2015, at 7:00 p.m.
All RAC meetings are subject to cancellation. For status of meeting prior to attendance, please contact the person listed under
The meeting will be held at the Sanders County Courthouse, 1111 Main Street Thompson Falls, Montana.
Written comments may be submitted as described under
John Gubel, Designated Federal Officer, by phone at 406-827-3533 or via email at
Individuals who use telecommunication devices for the deaf (TDD) may call the Federal Information Relay Service (FIRS) at 1-800-877-8339 between 8:00 a.m. and 8:00 p.m., Eastern Standard Time, Monday through Friday.
The purpose of the meeting is:
1. Review and approve previous meeting minutes;
2. Discuss status of RAC and memberships;
3. Review progress status of approved projects and discuss monitoring;
4. Review project proposals submitted; and
5. Open forum for public discussion.
The meeting is open to the public. The agenda will include time for people to make oral statements of three minutes or less. Individuals wishing to make an oral statement should request in writing by September 1, 2015, to be scheduled on the agenda. Anyone who would like to bring related matters to the attention of the committee may file written statements with the committee staff before or after the meeting. Written comments and requests for time to make oral comments must be sent to Robin Walker, RAC Coordinator, P.O. Box 429, Plains, Montana 59859; by email to
Forest Service, USDA.
Notice of meeting.
The Sanders Resource Advisory Committee (RAC) will meet in Thompson Falls, Montana. The committee is authorized under the Secure Rural Schools and Community Self-Determination Act (the Act) and operates in compliance with the Federal Advisory Committee Act. The purpose of the committee is to improve collaborative relationships and to provide advice and recommendations to the Forest Service concerning projects and funding consistent with Title II of the Act. Additional RAC information, including the meeting agenda and the meeting summary/minutes can be found at the following Web site:
The meeting will be held October 8, 2015, at 7:00 p.m.
All RAC meetings are subject to cancellation. For status of meeting prior to attendance, please contact the person listed under
The meeting will be held at the Sanders County Courthouse, 1111 Main Street, Thompson Falls, Montana.
Written comments may be submitted as described under
John Gubel, Designated Federal Officer, by phone at 406-827-3533 or via email at
Individuals who use telecommunication devices for the deaf (TDD) may call the Federal Information Relay Service (FIRS) at 1-800-877-8339 between 8:00 a.m. and 8:00 p.m., Eastern Standard Time, Monday through Friday.
The purpose of the meeting is:
1. Review and approve previous meeting minutes;
2. Discuss project proposals and address project specific questions;
3. Discuss project recommendations and rankings;
4. Vote on projects to be recommended for approval; and
5. Open forum for public discussion.
The meeting is open to the public. The agenda will include time for people to make oral statements of three minutes or less. Individuals wishing to make an oral statement should request in writing by October 1, 2015, to be scheduled on the agenda. Anyone who would like to bring related matters to the attention of the committee may file written statements with the committee staff before or after the meeting. Written comments and requests for time for oral comments must be sent to Robin Walker, RAC Coordinator, P.O. Box 429, Plains, Montana 59859; by email to
Forest Service, USDA.
Notice of meeting.
The Deschutes Provincial Advisory Committee (RAC) will meet in Bend, Oregon. The committee is authorized under the Secure Rural Schools and Community Self-Determination Act (the Act) and operates in compliance with the Federal Advisory Committee Act. The purpose of the committee is to improve collaborative relationships and to provide advice and recommendations to the Forest Service concerning projects and funding consistent with Title II of the Act. Additional PAC information, including the meeting agenda and the meeting summary/minutes can be found at the following Web site:
The meeting will be held on September 29, 2015, from 9 a.m. to 12 p.m.
All PAC meetings are subject to cancellation. For status of meeting prior to attendance, please contact the person listed under
The meeting will be held at the Deschutes National Forest Headquarters Office, Ponderosa Conference Room, 63095 Deschutes Market Road, Bend, Oregon.
Written comments may be submitted as described under
Beth Peer, PAC Coordinator, by phone at 541-383-4769 or via email at
Individuals who use telecommunication devices for the deaf (TDD) may call the Federal Information Relay Service (FIRS) at 1-800-877-8339 between 8:00 a.m. and 8:00 p.m., Eastern Standard Time, Monday through Friday.
The purpose of the meeting is to:
1. Introduce newly appointed committee members;
2. Review the history and accomplishments of the PAC under previous charters;
3. Discuss the goals and objectives of the PAC; and
4. Discuss the expected program of work for the year.
The meeting is open to the public. The agenda will include time for people to make oral statements of three minutes or less. Individuals wishing to make an oral statement should request in writing by September 15, 2015, to be scheduled on the agenda. Anyone who would like to bring related matters to the attention of the committee may file written statements with the committee staff before or after the meeting. Written comments and requests for time to make oral comments must be sent to Beth Peer, Deschutes PAC Coordinator, 63095 Deschutes Market Road, Bend, Oregon, 97701; by email to
Bureau of the Census, Department of Commerce.
Notice of public meeting.
The Bureau of the Census (Census Bureau) is giving notice of a meeting of the Census Scientific Advisory Committee (C-SAC). The Committee will address policy, research, and technical issues relating to a full range of Census Bureau programs and activities, including communications, decennial, demographic, economic, field operations, geographic, information technology, and statistics. The C-SAC will meet in a plenary session on September 17-18, 2015. Last minute changes to the schedule are possible, which could prevent giving advance public notice of schedule adjustments. Please visit the Census Advisory Committees Web site for the most current meeting agenda at:
September 17-18, 2015. On September 17, the meeting will begin at approximately 8:30 a.m. and end at approximately 4:15 p.m. On September 18, the meeting will begin at approximately 8:30 a.m. and end at approximately 12:15 p.m.
The meeting will be held at the U.S. Census Bureau Auditorium, 4600 Silver Hill Road, Suitland, Maryland 20746.
Kim Collier, Assistant Division Chief for Stakeholders, Customer Liaison and Marketing Services Office,
Members of the C-SAC are appointed by the Director, U.S. Census Bureau. The Committee provides scientific and technical expertise, as appropriate, to address Census Bureau program needs and objectives. The Committee has been established in accordance with the Federal Advisory Committee Act (title 5, United States Code, Appendix 2, section 10).
All meetings are open to the public. A brief period will be set aside at the meeting for public comment on September 18. However, individuals with extensive questions or statements must submit them in writing to:
If you plan to attend the meeting, please register by Tuesday, September 15, 2015. You may access the online registration from the following link:
This meeting is physically accessible to people with disabilities. Requests for sign language interpretation or other auxiliary aids should also be directed to the Committee Liaison Officer as soon as known, and preferably two weeks prior to the meeting.
Due to increased security and for access to the meeting, please call 301-763-9906 upon arrival at the Census Bureau on the day of the meeting. A photo ID must be presented in order to receive your visitor's badge. Visitors are not allowed beyond the first floor.
Topics to be discussed include the following items:
On April 22, 2015, the Greater Baton Rouge Port Commission, grantee of FTZ 154, submitted a notification of proposed production activity to the Foreign-Trade Zones (FTZ) Board on behalf of Syngenta Crop Protection, LLC, within Subzone 154B, located at sites in St. Gabriel and Baton Rouge, Louisiana.
The notification was processed in accordance with the regulations of the FTZ Board (15 CFR part 400), including notice in the
Enforcement and Compliance, International Trade Administration, Department of Commerce.
The Department of Commerce (the “Department”) preliminarily determines that certain uncoated paper (“uncoated paper”) from Brazil is being, or is likely to be, sold in the United States at less than fair value (“LTFV”), as provided in section 733(b) of the Tariff Act of 1930, as amended (“the Act”). The period of investigation (“POI”) is January 1, 2014, through December 31, 2014. The estimated weighted-average dumping margins of sales at LTFV are shown in the “Preliminary Determination” section of this notice. Interested parties are invited to comment on this preliminary determination.
Julia Hancock or Paul Walker, AD/CVD Operations, Office V, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 14th Street and Constitution Avenue NW., Washington, DC 20230; telephone: (202) 482-1394 or (202) 482-0413, respectively.
On February 10, 2015, the Department initiated the antidumping duty investigation on uncoated paper from Brazil.
For a complete description of the events that followed the initiation of this investigation, see the Preliminary Decision Memorandum.
The product covered by this investigation is uncoated paper from Brazil. For a full description of the scope of this investigation,
Certain interested parties commented on the scope of the investigation as it appeared in the
On May 18, 2015, Petitioners
The Department is conducting this investigation in accordance with section 731 of the Act. There are two mandatory respondents participating in this investigation, International Paper
Consistent with sections 733(d)(1)(A)(ii) and 735(c)(5) of the Act, the Department also calculated an estimated all-others rate. Section 735(c)(5)(A) of the Act provides that the estimated all-others rate shall be an amount equal to the weighted average of the estimated weighted-average dumping margins established for exporters and producers individually investigated, excluding any zero and
Specifically, this rate of 37.76 percent is based on a simple average of the
The Department preliminarily determines that the following weighted-average dumping margins
In accordance with section 733(d)(2) of the Act, we are directing U.S. Customs and Border Protection (“CBP”) to suspend liquidation of all entries of uncoated paper from Brazil, as described in Appendix I of this notice, entered, or withdrawn from warehouse, for consumption on or after the date of publication of this notice in the
In accordance with 19 CFR 351.205(d), the Department will instruct CBP to require a cash deposit equal to the preliminary weighted-average amount by which normal value exceeds U.S. price, as indicated in the chart above.
We will disclose the calculations performed to interested parties in this proceeding within five days of the date of the announcement of our preliminary determination in accordance with 19 CFR 351.224(b).
As provided in section 782(i) of the Act and 19 CFR 351.307, we intend to verify information relied upon in making our final determination.
Interested parties are invited to comment on this preliminary 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 final verification report is issued in this proceeding, and 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 must submit a written request to the Assistant Secretary for Enforcement and Compliance, U.S. Department of Commerce. All documents must be filed electronically using ACCESS. An electronically-filed request must be received successfully in its entirety by ACCESS by 5:00 p.m. Eastern Time, within 30 days after the date of publication of this notice.
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 Petitioners. Pursuant to 19 CFR 351.210(e)(2) requests by respondents for postponement of a final antidumping determination must 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 13, 2015, pursuant to 19 CFR 351.210(b) and (e), International Paper requested that, contingent upon an affirmative preliminary determination of sales at LTFV, the Department postpone the final determination and that provisional measures be extended to a period not to exceed six months.
In accordance with section 735(a)(2)(A) of the Act and 19 CFR 351.210(b)(2)(ii), because (1) our preliminary determination is affirmative; (2) the requesting exporters account for a significant proportion of exports of the subject merchandise; and (3) no compelling reasons for denial exist, we are postponing the final determination and extending the provisional measures from a four-month period to a period not greater than six months. Accordingly, we will make our final determination no later than 135 days after the date of publication of this preliminary determination, pursuant to section 735(a)(2) of the Act.
In accordance with section 733(f) of the Act, we have notified the ITC of our affirmative preliminary determination of sales at LTFV. If our final determination is affirmative, the ITC will determine
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 includes uncoated paper in sheet form; weighing at least 40 grams per square meter but not more than 150 grams per square meter; that either is a white paper with a GE brightness level of 85 or higher or is a colored paper; whether or not surface-decorated, printed (except as described below), embossed, perforated, or punched; irrespective of the smoothness of the surface; and irrespective of dimensions (Certain Uncoated Paper).
Certain Uncoated Paper includes (a) uncoated free sheet paper that meets this scope definition; (b) uncoated ground wood paper produced from bleached chemi-thermo-mechanical pulp (“BCTMP”) that meets this scope definition; and (c) any other uncoated paper that meets this scope definition regardless of the type of pulp used to produce the paper.
Specifically excluded from the scope are (1) paper printed with final content of printed text or graphics and (2) lined paper products, typically school supplies, composed of paper that incorporates straight horizontal and/or vertical lines that would make the paper unsuitable for copying or printing purposes.
Imports of the subject merchandise are provided for under Harmonized Tariff Schedule of the United States (“HTSUS”) categories 4802.56.1000, 4802.56.2000, 4802.56.3000, 4802.56.4000, 4802.56.6000, 4802.56.7020, 4802.56.7040, 4802.57.1000, 4802.57.2000, 4802.57.3000, and 4802.57.4000. Some imports of subject merchandise may also be classified under 4802.62.1000, 4802.62.2000, 4802.62.3000, 4802.62.5000, 4802.62.6020, 4802.62.6040, 4802.69.1000, 4802.69.2000, 4802.69.3000, 4811.90.8050 and 4811.90.9080. While HTSUS subheadings are provided for convenience and customs purposes, the written description of the scope of the investigation is dispositive.
Enforcement and Compliance, International Trade Administration, Department of Commerce.
The Department of Commerce (“Department”) is initiating a new shipper review of the antidumping duty order on xanthan gum from the People's Republic of China (“PRC”) with respect to Inner Mongolia Jianlong Biochemical Co., Ltd. (“Inner Mongolia Jianlong”). The period of review (“POR”) for the new shipper review is July 1, 2014, through June 30, 2015.
Brandon Farlander, AD/CVD Operations, Office IV, Enforcement and Compliance, International Trade Administration, U.S. Department of Commerce, 14th Street and Constitution Avenue NW., Washington, DC 20230; telephone: (202) 482-0182.
The Department published the antidumping duty order on xanthan gum from the PRC on July 19, 2013.
Inner Mongolia Jianlong reported that it was the producer and exporter for the sale of subject merchandise upon which the request for the new shipper review is based.
Pursuant to section 751(a)(2)(B)(i)(I) of the Act and 19 CFR 351.214(b)(2)(i), Inner Mongolia Jianlong certified that it did not export xanthan gum to the United States during the period of investigation (“POI”).
In addition, pursuant to 19 CFR 351.214(b)(2)(iv), Inner Mongolia Jianlong submitted documentation concerning the following: (1) The date
The Department conducted a CBP database query and confirmed by examining the results of the CBP data query that Inner Mongolia Jianlong's subject merchandise entered the United States during the POR specified by the Department's regulations.
Pursuant to 19 CFR 351.214(g)(1)(i)(A), the POR for the new shipper review of Inner Mongolia Jianlong is July 1, 2014, through June 30, 2015.
Pursuant to section 751(a)(2)(B) of the Act, 19 CFR 351.214(b), and based on the information on the record, the Department finds that Inner Mongolia Jianlong meets the threshold requirements for initiation of a new shipper review of its shipment of xanthan gum from the PRC.
Pursuant to 19 CFR 351.221(c)(1)(i), the Department will publish the notice of initiation of a new shipper review no later than the last day of the month following the anniversary month or semiannual anniversary month of the order. The Department intends to issue the preliminary results of this review no later than 180 days from the date of initiation, and the final results of this review no later than 90 days after the date the preliminary results are issued.
It is the Department's usual practice, in cases involving non-market economies (“NME”), to require that a company seeking to establish eligibility for an antidumping duty rate separate from the NME-wide entity to provide evidence of the absence of
The Department will instruct CBP to allow, at the option of the importer, the posting, until the completion of the review, of a bond or security in lieu of a cash deposit for entries of subject merchandise from Inner Mongolia Jianlong in accordance with section 751(a)(2)(B)(iii) of the Act and 19 CFR 351.214(e). Because Inner Mongolia Jianlong certified that it produced and exported the subject merchandise that is the subject of this new shipper review, the Department will apply the bonding privilege only for subject merchandise produced and exported by Inner Mongolia Jianlong.
Interested parties requiring access to proprietary information in this new shipper review should submit applications for disclosure under administrative protective order in accordance with 19 CFR 351.305 and 351.306.
This initiation notice is published in accordance with section 751(a)(2)(B) of the Act and 19 CFR 351.214 and 351.221(c)(1)(i).
National Institute of Standards and Technology, Commerce.
Notice.
The Department of Commerce, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to take this opportunity to comment on proposed and/or continuing information collections, as required by the Paperwork Reduction Act of 1995.
Written comments must be submitted on or before October 26, 2015.
Direct all written comments to Jennifer Jessup, Departmental Paperwork Clearance Officer, Department of Commerce, Room 6616, 14th and Constitution Avenue NW., Washington, DC 20230 (or via the Internet at
Requests for additional information or copies of the information collection instrument and instructions should be directed to Dawn Bailey, Baldrige Performance Excellence Program, 100 Bureau Drive, Stop 1020, Gaithersburg, MD 20899, 301-975-3074,
The Baldrige Performance Excellence Program seeks applicants for the Baldrige Executive Fellows Program, a one-year, leadership development experience for direct reports to the most senior leader in an organization or business unit leaders. Using the Baldrige Excellence Framework as a foundation, the program discusses impactful leadership through visits to Baldrige Award recipient sites and senior leaders, virtual discussions, and face-to-face peer training using an adult learning model. Fellows will discuss how to achieve performance excellence for their own organizations, stimulate innovation, and build the knowledge and capabilities necessary for organizational sustainability. Fellows will create a capstone project that tackles an issue of strategic importance in their own organizations; capstones have included innovating supply chains and customer relationship management systems, improving health systems and their communication with physicians, and creating balanced scorecards. The Baldrige Executive Fellows has been nationally recognized for two consecutive years as the number-one leadership development program in the military/government category of the Leadership 500 Awards, sponsored by HR.com. The program is aligned with the Baldrige Program mission to
Senior leaders interested in applying for selection as a Baldrige Fellow must
1. A resumé, including email, postal address, and telephone contact information; and the name and email address of an assistant or alternate contact person
2. An organizational chart that includes names and titles showing the applicant's position within the organization
3. A recommendation letter from the applicant's highest-ranking official showing the organization's support of his/her participation in the program
4. A list of key competitors (in order that the Baldrige Program may avoid creating a cohort that would be unable to share effectively due to competitive situations)
Fax is also acceptable. The NIST Secure File Transfer Service (“N-files”) is also made available for applicants who wish to electronically submit materials that include personally identifiable information.
Information is collected one time per year (typically in September-December) for each cohort of Fellows.
Information is need to make selection decisions that are based on (1) sector mix, (2) appropriate level within the organization, (3) likelihood to follow through, (4) diversity, and (5) no direct competitors with participating award recipients or other Fellows.
Comments are invited on: (a) Whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information shall have practical utility; (b) the accuracy of the agency's estimate of the burden (including hours and cost) of the proposed collection of information; (c) ways to enhance the quality, utility, and clarity of the information to be collected; and (d) ways to minimize the burden of the collection of information on respondents, including through the use of automated collection techniques or other forms of information technology.
Comments submitted in response to this notice will be summarized and/or included in the request for OMB approval of this information collection; they also will become a matter of public record.
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice of non-compliance referral; request for comments.
NMFS announces that on August 6, 2015, the Atlantic States Marine Fisheries Commission (Commission) found the State of Delaware out of compliance with the Commission's Interstate Fishery Management Plan (ISFMP) for American Eel. Subsequently, on August 19, 2015, the Commission referred the matter to NMFS, under delegation of authority from the Secretary of Commerce, for federal non-compliance review under the provisions of the Atlantic Coastal Fisheries Cooperative Management Act (Atlantic Coastal Act). The Atlantic Coastal Act mandates that NMFS must review the Commission's non-compliance referral and make specific findings by September 18, 2015, 30 days after receiving the referral. If NMFS determines that Delaware failed to carry out its responsibilities under the Coastal American Eel ISFMP, and if the measures it failed to implement are necessary for conservation, then, according to the Atlantic Coastal Act, NMFS must declare a moratorium on fishing for American eel in Delaware waters.
Comments must be submitted by September 11, 2015. NMFS intends to make a determination on this matter by September 18, 2015, and will publish its findings in the
Written comments should be sent to Derek Orner, Office of Sustainable Fisheries, NMFS, 1315 East-West Highway, Room 13325, Silver Spring, MD 20910. Mark the outside of the envelope “Comments on American eel Non-Compliance.” Comments may also be sent via fax to (301) 713-0596 or by email to
Derek Orner, Fishery Management Specialist, NMFS Office of Sustainable Fisheries, (301) 427-8567,
The 2012 Benchmark Stock Assessment for American eel found that the American eel population in U.S. waters is depleted. The assessment concluded that the stock is at or near historically low levels due to a combination of historical overfishing, habitat loss and alteration, productivity and food web alterations, predation, turbine mortality, changing climatic and oceanic conditions, toxins and contaminants, and disease. As a result, the Commission took action to reduce mortality and limit further development of this fishery. In order to achieve the conservation goals and objectives of the ISFMP, states were to effectively implement the following actions: A 9″ minimum size for yellow eel (the life stage when eels are typically harvested as bait) recreational and commercial fisheries;
Federal response to a Commission non-compliance referral is governed by
NMFS has notified the State of Delaware, the Commission, and the Mid-Atlantic Fishery Management Council in separate letters, of its receipt of the Commission's non-compliance referral. In the letters, NMFS solicits comments from the Commission and Councils to the extent either entity is interested in providing such comments. NMFS also indicated to the State of Delaware that the State is entitled to meet with and present its comments directly to NMFS if the State so desires.
NMFS intends to make its non-compliance determination on or about September 18, 2015, which is 30 days after receipt of the Commission's non-compliance referral. NMFS will announce its determination by
16 U.S.C. 5101
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice; receipt of application for permit amendment.
Notice is hereby given that Dan Engelhaupt, Ph.D., HDR EOC, 5700 Lake Wright Drive, Norfolk, VA 23502-1859, has applied for an amendment to Scientific Research Permit No. 16239.
Written, telefaxed, or email comments must be received on or before September 28, 2015.
The application and related documents are available for review by selecting “Records Open for Public Comment” from the “Features” box on the Applications and Permits for Protected Species home page,
These documents are also available upon written request or by appointment in the Permits and Conservation Division, Office of Protected Resources, NMFS, 1315 East-West Highway, Room 13705, Silver Spring, MD 20910; phone (301) 427-8401; fax (301) 713-0376.
Written comments on this application should be submitted to the Chief, Permits and Conservation Division, at the address listed above. Comments may also be submitted by facsimile to (301) 713-0376, or by email to
Those individuals requesting a public hearing should submit a written request to the Chief, Permits and Conservation Division at the address listed above. The request should set forth the specific reasons why a hearing on this application would be appropriate.
Carrie Hubard or Courtney Smith, (301) 427-8401.
The subject amendment to Permit No. 16239 is requested under the authority of the Marine Mammal Protection Act of 1972, as amended (16 U.S.C. 1361
Permit No. 16239, issued on September 11, 2013 (78 FR 60852), authorizes the permit holder to harass cetacean and pinniped species during vessel and aerial survey activities, including behavioral observations and photo-identification. Cetacean species may also be harassed during underwater photography and collection of sloughed skin and fecal samples. Surveys may be conducted year-round in all U.S. and international waters in the Pacific Ocean (including Alaska, Washington, Oregon, California, Hawaii, Guam, Marianas Islands, and other U.S. territories) and Atlantic Ocean (including the Gulf of Mexico, western North Atlantic, Caribbean Sea, and Sargasso Seas). The permit expires September 30, 2018.
The permit holder is requesting the permit be amended to include authorization for: (1) Increasing takes for some species during aerial and vessel visual surveys to document presence/absence, behavior, and movement of marine mammals before, during, and after Naval training exercise operations, offshore energy installations, oil and gas exploration and production, and pier refurbishment/replacement; (2) collecting biopsy samples to document genetic variation within populations, gender, foraging patterns, and stress levels; and (3) using multiple tag types, including satellite and digital acoustic tags, to document movement and dive patterns, social and population structure, and habitat use. See tables in the permit amendment application for numbers of takes by species, stock and activity. The research would be conducted to collect data on population and genetic variations and habitat use, and to monitor behavioral changes during activities associated with U.S. Navy, renewable energy, oil and gas exploration and production, and pier-based construction.
In compliance with the National Environmental Policy Act of 1969 (42 U.S.C. 4321
Concurrent with the publication of this notice in the
National Marine Fisheries Service (NMFS), National Oceanic and Atmospheric Administration (NOAA), Commerce.
Notice; receipt of application.
Notice is hereby given that Iain Kerr, D.H.L., Ocean Alliance, 32 Horton Street, Gloucester, MA 01930, has applied in due form for a permit to conduct research on multiple cetacean species.
Written, telefaxed, or email comments must be received on or before September 28, 2015.
The application and related documents are available for review by selecting “Records Open for Public Comment” from the “Features” box on the Applications and Permits for Protected Species (APPS) home page,
These documents are also available upon written request or by appointment in the Permits and Conservation Division, Office of Protected Resources, NMFS, 1315 East-West Highway, Room 13705, Silver Spring, MD 20910; phone (301) 427-8401; fax (301) 713-0376.
Written comments on this application should be submitted to the Chief, Permits and Conservation Division, at the address listed above. Comments may also be submitted by facsimile to (301) 713-0376, or by email to
Those individuals requesting a public hearing should submit a written request to the Chief, Permits and Conservation Division at the address listed above. The request should set forth the specific reasons why a hearing on this application would be appropriate.
Courtney Smith or Amy Hapeman, (301) 427-8401.
The subject permit is requested under the authority of the Marine Mammal Protection Act of 1972, as amended (MMPA; 16 U.S.C. 1361
The applicant requests a five-year permit to determine how environmental toxicants affect cetaceans and vary spatially and temporally across species; and determine the route of exposure. Research would occur in U.S. waters and the high seas of the Pacific, Atlantic and Indian Oceans via vessel surveys targeting live cetaceans, tissue collection of dead, stranded cetaceans, and the import/export/receipt of biological samples collected in foreign waters/countries. Field research activities on live animals would include collection of sloughed skin and feces, biopsy sampling, photo-identification, videography, passive acoustic recording, focal follows, behavioral observation, and breath sampling via a small unmanned aircraft system. The applicant requests to annually harass and sample the following species during vessel surveys as follows. In the North Atlantic: 150 takes for the primary study species, sperm whales (
Additionally, the applicant requests to annually import/export/receive up to 150 biological samples (parts) for sperm whales; 200 parts for southern right whales; 40 parts for humpback whales; 30 parts for Bryde's whales; and 20 parts for all other requested species.
In compliance with the National Environmental Policy Act of 1969 (42 U.S.C. 4321
Concurrent with the publication of this notice in the
Commodity Futures Trading Commission.
Notice.
In compliance with the Paperwork Reduction Act of 1995 (“PRA”), this notice announces that the Information Collection Request (“ICR”) abstracted below has been forwarded to the Office of Management and Budget (“OMB”) for review and comment. The ICR describes the nature of the information collection and its expected costs and burden.
Comments must be submitted on or before September 28, 2015.
Comments regarding the burden estimated or any other aspect of the information collection, including suggestions for reducing the burden, may be submitted directly to the Office of Information and Regulatory Affairs (“OIRA”) in OMB, within 30 days of the notice's publication, by email at
Comments may also be mailed to the Office of Information and Regulatory Affairs, Office of Management and Budget, Attention: Desk Officer for the Commodity Futures Trading Commission, 725 17th Street NW., Washington, DC 20503. You may also submit comments, identified by Renewal of Collection Number 3038-0007 and “Regulation of Domestic Exchange-Traded Options,” by any of the following methods:
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All comments must be submitted in English, or if not, accompanied by an English translation. Comments will be posted as received to
The Commission reserves the right, but shall have no obligation, to review, pre-screen, filter, redact, refuse or remove any or all of your submission from
Commodity Futures Trading Commission, Three Lafayette Centre, 1155 21st Street NW., Washington, DC 20581; Dana R. Brown, Division of Market Oversight, telephone: (202) 418-5093 and email:
There are no capital costs or operating and maintenance costs associated with this collection.
44 U.S.C. 3501
Commodity Futures Trading Commission.
Notice.
In compliance with the Paperwork Reduction Act of 1995 (“PRA”), this notice announces that the Information Collection Request (“ICR”) abstracted below has been forwarded to the Office of Management and Budget (“OMB”) for review and comment. The ICR describes the nature of the information collection and its expected costs and burden.
Comments must be submitted on or before September 28, 2015.
Comments regarding the burden estimated or any other aspect of the information collection, including suggestions for reducing the burden, may be submitted directly to the Office of Information and Regulatory Affairs (“OIRA”) in OMB, within 30 days of the notice's publication, by email at
Comments may also be mailed to the Office of Information and Regulatory Affairs, Office of Management and Budget, Attention: Desk Officer for the Commodity Futures Trading Commission, 725 17th Street NW., Washington, DC 20503, and to: Christopher Kirkpatrick, Secretary of the Commission, Commodity Futures Trading Commission, 1155 21st Street
A copy of the supporting statements for the collection of information discussed above may be obtained by visiting
Lois Gregory, Associate Director, Division of Market Oversight, Commodity Futures Trading Commission, (202) 418-5569, email:
Advisory Committee on Student Financial Assistance, Education.
Announcement of open teleconference meeting.
This notice sets forth the schedule and proposed agenda of a forthcoming open teleconference meeting of the Advisory Committee on Student Financial Assistance. This notice also describes the functions of the Advisory Committee. Notice of this meeting is required under Section 10(a)(2) of the Federal Advisory Committee Act. This document is intended to notify the general public of their opportunity to attend.
The Committee will meet via teleconference on Wednesday, September 9, 2015, beginning at 3:00 p.m. and ending at approximately 3:30 p.m. (EDT).
Office of the Advisory Committee on Student Financial Assistance, Capitol Place, 555 New Jersey Ave NW., Suite 522, Washington DC 20202-7582.
Ms. Tracy Jones, Executive Officer, Advisory Committee on Student Financial Assistance, Capitol Place, 555 New Jersey Ave NW., Suite 522, Washington DC 20202-7582, (202) 219-2099.
The Advisory Committee has scheduled this teleconference for the sole purpose of electing an ACSFA member to serve as chair and a member to serve as vice-chair for one year beginning October 1, 2015.
Space at the New Jersey Avenue meeting site and “dial-in” (listen only) line for the teleconference meeting is limited, and you are encouraged to register early if you plan to attend. You may register by sending an email to the following email address:
You may also access documents of the Department published in the
Section 491 of the Higher Education Act of 1965 as amended by Public Law 100-50 (20 U.S.C. 1098).
Office of Career, Technical, and Adult Education, Department of Education.
Notice.
The Secretary of Education invites publishers to submit tests for review and approval for use in the National Reporting System for Adult Education (NRS) and announces the date by which publishers must submit these tests.
Deadline for transmittal of applications: October 1, 2015.
Submit your application by mail (through the U.S. Postal Service or a commercial carrier) or deliver your application by hand or by courier service to: NRS Assessment Review, c/o American Institutes for Research, 1000 Thomas Jefferson Street NW., Washington, DC 20007.
Jay LeMaster, U.S. Department of Education, 400 Maryland Avenue SW., Room 11152, Potomac Center Plaza, Washington, DC 20202-7240. Telephone: (202) 245-6218 or by 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's regulations for Measuring Educational Gain in the National Reporting System for Adult Education, 34 CFR part 462 (NRS regulations), include the procedures for determining the suitability of tests for use in the NRS.
(a) In preparing your application, you must comply with the requirements in § 462.11.
(b) In accordance with § 462.10, the deadline for transmittal of applications is October 1.
(c) Whether you submit your application by mail (through the U.S. Postal Service or a commercial carrier) or deliver your application by hand or by courier service, you must mail or deliver three copies of your application, on or before the deadline date, to the following address:
NRS Assessment Review, c/o American Institutes for Research, 1000 Thomas Jefferson Street NW., Washington, DC 20007.
(d) If you submit your application by mail or commercial carrier, you must show proof of mailing consisting of one of the following:
(1) A legibly dated U.S. Postal Service postmark.
(2) A legible mail receipt with the date of mailing stamped by the U.S. Postal Service.
(3) A dated shipping label, invoice, or receipt from a commercial carrier.
(4) Any other proof of mailing acceptable to the Secretary of Education.
(e) If you mail your application through the U.S. Postal Service, we do not accept either of the following as proof of mailing:
(1) A private metered postmark.
(2) A mail receipt that is not dated by the U.S. Postal Service.
(f) If your application is postmarked after the application deadline date, we will not consider your application.
The U.S. Postal Service does not uniformly provide a dated postmark. Before relying on this method, you should check with your local post office.
(g) If you submit your application by hand delivery, you (or a courier service) must deliver three copies of the application by hand, on or before 4:30:00 p.m., Washington, DC time, on the application deadline date.
You may also access documents of the Department published in the
20 U.S.C. 9212.
Office of Electricity Delivery and Energy Reliability, U.S. Department of Energy.
Request for Information; re-opening of comment period.
On July 1, 2015, the Department of Energy (DOE) published in the
The comment period for the RFI published July 1, 2015 (80 FR 37606) is re-opened. Written comments must be received on or before October 26, 2015.
Comments can be submitted by any of the following methods and must be identified by “EGRtool”. By email:
Mr. Dan Ton, Office of Electricity Delivery and Energy Reliability, U.S. Department of Energy, Forrestal Building, Room 6E-092, 1000 Independence Avenue SW., Washington, DC 20585 or by email at
On July 1, 2015, the DOE published a request for information in the
The July 1 notice requested comments and information from interested parties to inform the development of a pilot project concerning an interactive self-assessment tool by August 17, 2015. DOE is re-opening the comment period by 60 days to allow additional time for more substantive comment on the significant questions to which DOE is seeking response. DOE believes that re-opening the comment period to allow additional time for interested parties to submit comments is appropriate. Therefore, DOE is re-opening the comment period to provide interested parties additional time to prepare and submit comments and will consider any comments received by that date.
Office of Energy Efficiency and Renewable Energy, Department of Energy.
Notice.
In this notice, the U.S. Department of Energy (DOE) is forecasting the representative average unit costs of five residential energy sources for the year 2015 pursuant to the Energy Policy and Conservation Act. The five sources are electricity, natural gas, No. 2 heating oil, propane, and kerosene.
The representative average unit costs of energy contained in this notice will become effective September 28, 2015 and will remain in effect until further notice.
John Cymbalsky, U.S. Department of Energy, Office of Energy Efficiency and Renewable Energy Forrestal Building, Mail Station EE-5B, 1000 Independence Avenue SW., Washington, DC 20585-0121, (202) 287-1692,
Francine Pinto, Esq. U.S. Department of Energy, Office of General Counsel Forrestal Building, Mail Station GC-33, 1000 Independence Avenue SW., Washington, DC 20585-0103, (202) 586-7432,
Section 323 of the Energy Policy and Conservation Act (Act) requires that DOE prescribe test procedures for the measurement of the estimated annual operating costs or other measures of energy consumption for certain consumer products specified in the Act. (42 U.S.C. 6293(b)(3)) These test procedures are found in title 10 of the Code of Federal Regulations (CFR) part 430, subpart B.
Section 323(b)(3) of the Act requires that the estimated annual operating costs of a covered product be calculated from measurements of energy use in a representative average use cycle or period of use and from representative average unit costs of the energy needed to operate such product during such cycle. (42 U.S.C. 6293(b)(3)) The section further requires that DOE provide information to manufacturers regarding the representative average unit costs of energy. (42 U.S.C. 6293(b)(4)) This cost information should be used by manufacturers to meet their obligations under section 323(c) of the Act. Most notably, these costs are used to comply with Federal Trade Commission (FTC) requirements for labeling. Manufacturers are required to use the revised DOE representative average unit costs when the FTC publishes new ranges of comparability for specific covered products, 16 CFR part 305. Interested parties can also find information covering the FTC labeling requirements at
DOE last published representative average unit costs of residential energy in a
On September 28, 2015, the cost figures published in this notice will become effective and supersede those cost figures published on March 18, 2014. The cost figures set forth in this notice will be effective until further notice.
DOE's Energy Information Administration (EIA) has developed the 2015 representative average unit after-tax residential costs found in this notice. These costs for electricity, natural gas, No. 2 heating oil, and propane are based on simulations used to produce the August 2015, EIA
The 2015 representative average unit costs under section 323(b)(4) of the Act are set forth in Table 1, and will become effective September 28, 2015. They will remain in effect until further notice.
Take notice that the Commission received the following electric corporate 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:
On August 13, 2015, West Valley Water District filed a notice of intent to construct a qualifying conduit hydropower facility, pursuant to section 30 of the Federal Power Act (FPA), as amended by section 4 of the Hydropower Regulatory Efficiency Act of 2013 (HREA). The proposed Roemer Water Filtration Facility Hydroelectric Project would have an installed capacity of 484 kilowatts (kW) and would be located on the existing West Valley Water District's raw water 30-inch-diameter Lytle Creek Turnout pipe into the Roemer Water Filtration Facility. The project would be located near the City of Rialto in San Bernardino County, California.
A qualifying conduit hydropower facility is one that is determined or deemed to meet all of the criteria shown in the table below.
Deadline for filing motions to intervene is 30 days from the issuance date of this notice.
Anyone may submit comments or a motion to intervene in accordance with the requirements of Rules of Practice and Procedure, 18 CFR 385.210 and 385.214. Any motions to intervene must be received on or before the specified deadline date for the particular proceeding.
The Commission strongly encourages electronic filing. Please file motions to intervene and comments using the Commission's eFiling system at
Take notice that the following hydroelectric application has been filed with the Commission and is available for public inspection:
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All documents may be filed electronically via the Internet. See, 18 CFR 385.2001(a)(1)(iii) and the instructions on the Commission's Web site at
The Commission's Rules of Practice and Procedure require all intervenors filing documents with the Commission to serve a copy of that document on each person whose name appears on the official service list for the project. Further, if an intervenor files comments or documents with the Commission relating to the merits of an issue that may affect the responsibilities of a particular resource agency, they must also serve a copy of the document on that resource agency.
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m. Individuals desiring to be included on the Commission's mailing list should so indicate by writing to the Secretary of the Commission.
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On June 25, 2015, the Energy Resources USA Inc. filed an application for a preliminary permit under section 4(f) of the Federal Power Act proposing to study the feasibility of the proposed Lock and Dam No.11 Hydroelectric Project No. 14687-000, to be located at the existing Mississippi River Lock and Dam No. 11 on the Mississippi River, near the City of Dubuque, in Grant County, Wisconsin. The Mississippi River Lock and Dam No. 11 is owned by the United States government and operated by the U.S. Army Corps of Engineers.
The sole purpose of a preliminary permit, if issued, is to grant the permit holder priority to file a license application during the permit term. A preliminary permit does not authorize the permit holder to perform any land-disturbing activities or otherwise enter upon lands or waters owned by others without the owners' express permission.
The proposed project would consist of: (1) A new 770-foot-long by 300-foot-wide earthen intake area; (2) a new 220-foot by 90-foot concrete powerhouse containing four 2.5-megawatt hydropower turbine-generators having a total combined generating capacity of 10 megawatts; (3) one new 1000-foot-long by 220-foot-wide tailrace; (4) a new intake retaining wall and new tailrace retaining wall each measuring 85-foot-long by 43-foot-high by 3-foot-thick; (5) a new 50-foot by 60-foot switchyard; (6) a new 1.52-mile-long, 69-kilovolt transmission line; and (7) appurtenant facilities. The project would have an estimated annual generation of 119,655 megawatt-hours.
Deadline for filing comments, motions to intervene, competing applications (without notices of intent), or notices of intent to file competing applications: 60 days from the issuance of this notice. Competing applications and notices of intent must meet the requirements of 18 CFR 4.36. The Commission strongly encourages electronic filing. Please file comments, motions to intervene, notices of intent, and competing applications using the Commission's eFiling system at
More information about this project, including a copy of the application, can be viewed or printed on the “eLibrary” link of Commission's Web site at
1. Section 205 of the Federal Power Act (FPA), 16 U.S.C. 824d (2012), and 18 CFR part 35 (2015), require, among other things, that all rates, terms, and conditions of jurisdictional services be filed with the Commission. In Order No. 2001, the Commission revised its public utility filing requirements and established a requirement for public utilities, including power marketers, to file Electric Quarterly Reports summarizing the contractual terms and conditions in their agreements for all jurisdictional services (including market-based power sales, cost-based power sales, and transmission service) and providing transaction information (including rates) for short-term and long-term power sales during the most recent calendar quarter.
2. The Commission requires sellers with market-based rate authorization to file Electric Quarterly Reports.
3. In Order No. 2001, the Commission stated that,
4. The Commission further stated that,
5. Pursuant to these requirements, the Commission has revoked the market-based rate tariffs of market-based rate sellers that failed to submit their Electric Quarterly Reports.
6. Sellers must file Electric Quarterly Reports consistent with the procedures set forth in Order Nos. 768
7. In the event that any of the above-captioned market-based rate sellers has already filed its Electric Quarterly Reports in compliance with the Commission's requirements, its inclusion herein is inadvertent. Such market-based rate seller is directed, within 15 days of the date of issuance of this order, to make a filing with the Commission identifying itself and providing details about its prior filings that establish that it complied with the Commission's Electric Quarterly Report filing requirements.
8. If any of the above-captioned market-based rate sellers does not wish to continue having market-based rate authority, it may file a notice of cancellation with the Commission pursuant to section 205 of the FPA to cancel its market-based rate tariff.
(A) Within 15 days of the date of issuance of this order, each public utility listed in the caption of this order shall file with the Commission all delinquent Electric Quarterly Reports. If a public utility subject to this order fails to make the filings required in this order, the Commission will revoke that public utility's market-based rate authorization and will terminate its electric market-based rate tariff. The Secretary is hereby directed, upon expiration of the filing deadline in this order, to promptly issue a notice, effective on the date of issuance, listing the public utilities whose tariffs have been revoked for failure to comply with the requirements of this order and the Commission's Electric Quarterly Report filing requirements.
(B) The Secretary is hereby directed to publish this order in the
By the Commission.
Take notice that the Commission has received the following Natural Gas Pipeline Rate and Refund Report filings:
The filings are accessible in the Commission's eLibrary system by clicking on the links or querying the docket number.
Any person desiring to intervene or protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00 p.m. Eastern time on the specified comment date. Protests may be considered, but intervention is necessary to become a party to the proceeding.
eFiling is encouraged. More detailed information relating to filing requirements, interventions, protests, service, and qualifying facilities filings can be found at:
Take notice that the Commission received the following electric rate filings:
Take notice that the Commission received the following qualifying facility 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 of LRI Renewable Energy, 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 9, 2015.
The Commission encourages electronic submission of protests and interventions in lieu of paper, using the FERC Online links at
Persons unable to file electronically should submit an original and 5 copies of the intervention or protest to the Federal Energy Regulatory Commission, 888 First Street NE., Washington, DC 20426.
The filings in the above-referenced proceeding are accessible in the Commission's eLibrary system by clicking on the appropriate link in the above list. They are also available for electronic review in the Commission's Public Reference Room in Washington, DC. There is an eSubscription link on the Web site that enables subscribers to receive email notification when a document is added to a subscribed docket(s). For assistance with any FERC Online service, please email
The Centers for Disease Control and Prevention (CDC) has submitted the following information collection request to the Office of Management and Budget (OMB) for review and approval in accordance with the Paperwork Reduction Act of 1995. The notice for the proposed information collection is published to obtain comments from the public and affected agencies.
Written comments and suggestions from the public and affected agencies concerning the proposed collection of information are encouraged. Your comments should address any of the following: (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,
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
Minimum Data Elements (MDEs) for the National Breast and Cervical Cancer Early Detection Program (NBCCEDP) (OMB No. 0920-0571, exp. 10/31/2015)—Extension—National Center for Chronic Disease Prevention and Health
Many cancer-related deaths in women could be avoided by increased utilization of appropriate screening and early detection tests for breast and cervical cancer. Mammography is extremely valuable as an early detection tool because it can detect breast cancer well before the woman can feel the lump, when the cancer is still in an early and more treatable stage. Similarly, a substantial proportion of cervical cancer-related deaths could be prevented through the detection and treatment of precancerous lesions. The Papanicolaou (Pap) test is the primary method of detecting both precancerous cervical lesions as well as invasive cervical cancer. Mammography and Pap tests are underused by women who have no source or no regular source of health care and women without health insurance.
The CDC's National Breast and Cervical Cancer Early Detection Program (NBCCEDP) provides screening services to underserved women through cooperative agreements with 50 States, the District of Columbia, 5 U.S. Territories, and 11 American Indian/Alaska Native tribal programs. The program was established in response to the Breast and Cervical Cancer Mortality Prevention Act of 1990. Screening services include clinical breast examinations, mammograms and Pap tests, as well as timely and adequate diagnostic testing for abnormal results, and referrals to treatment for cancers detected. NBCCEDP awardees collect patient-level screening and tracking data to manage the program and clinical services. A de-identified subset of data on patient demographics, screening tests and outcomes are reported by each awardee to CDC twice per year.
CDC is requesting OMB approval to collect MDE information for an additional three years. There are no changes to the currently approved minimum data elements, electronic data collection procedures, or the estimated burden. Because NBCCEDP awardees already collect and aggregate data at the state, territory and tribal level, the additional burden of submitting data to CDC will be modest. CDC will use the information to monitor and evaluate NBCCEDP awardees; improve the availability and quality of screening and diagnostic services for underserved women; develop outreach strategies for women who are never or rarely screened for breast and cervical cancer, and report program results to Congress and other legislative authorities.
There are no costs to respondents other than their time. The total estimated annualized burden hours are 536.
Attendees who wish to attend the September 22-23, 2015 ICD-10-CM C&M meeting must submit their name and organization by September 11, 2015 for inclusion on the visitor list. This visitor list will be maintained at the front desk of the CMS building and used by the guards to admit visitors to the meeting.
Please register to attend the meeting on-line at:
Participants who attended previous Coordination and Maintenance meetings will no longer be automatically added to the visitor list. You must request inclusion of your name prior to each meeting you wish attend.
Purpose: The ICD-10 Coordination and Maintenance (C&M) Committee is a public forum for the presentation of proposed modifications to the International Classification of Diseases, Tenth Revision, Clinical Modification and ICD-10 Procedure Coding System.
ICD-10-PCS Topics:
ICD-10-CM Diagnosis Topics:
Agenda items are subject to change as priorities dictate.
The Director, Management Analysis and Services Office, has been delegated the authority to sign
Food and Drug Administration, HHS.
Notice.
The Food and Drug Administration (FDA or Agency) is announcing the availability of a document entitled “Design and Analysis of Shedding Studies for Virus or Bacteria-Based Gene Therapy and Oncolytic Products; Guidance for Industry.” The guidance document provides sponsors of virus or bacteria-based gene therapy products (VBGT products) and oncolytic viruses or bacteria (oncolytic products) with recommendations on how to conduct shedding studies during preclinical and clinical development. The guidance announced in this notice finalizes the draft guidance of the same title dated July 2014.
Submit either electronic or written comments on Agency guidances at any time.
Submit written requests for single copies of the guidance to the Office of Communication, Outreach and Development, Center for Biologics Evaluation and Research (CBER), Food and Drug Administration, 10903 New Hampshire Ave., Bldg. 71, Rm. 3128, Silver Spring, MD 20993-0002. Send one self-addressed adhesive label to assist the office in processing your requests. The guidance may also be obtained by mail by calling CBER at 1-800-835-4709 or 240-402-8010. See the
Submit electronic comments on the guidance to
Tami Belouin, Center for Biologics Evaluation and Research, Food and Drug Administration, 10903 New Hampshire Ave., Bldg. 71, Rm. 7301, Silver Spring, MD 20993-0002, 240-402-7911.
FDA is announcing the availability of a document entitled “Design and Analysis of Shedding Studies for Virus or Bacteria-Based Gene Therapy and Oncolytic Products; Guidance for Industry.” The guidance provides sponsors of VBGT and oncolytic products with recommendations on how to conduct shedding studies during preclinical and clinical development. VBGT and oncolytic products are derived from infectious viruses or bacteria. In general, these product-based viruses and bacteria are not as infectious or as virulent as the parent strain of virus or bacterium. Nonetheless, FDA is issuing this guidance because the possibility that infectious product-based viruses and bacteria may be shed by a patient raises safety concerns related to the risk of transmission to untreated individuals. To understand the risk associated with product shedding, sponsors should collect data in the target patient population in clinical trials before licensure.
In the
This guidance is being issued consistent with FDA's good guidance practices regulation (21 CFR 10.115). The guidance represents the current thinking of FDA on design and analysis of shedding studies for virus or bacteria-based gene therapy and oncolytic products. It does not establish any rights for any person and is not binding on FDA or the public. You can use an alternative approach if it satisfies the requirements of the applicable statutes and regulations.
This guidance refers to previously approved collections of information found in FDA regulations. These collections of information are subject to review by the Office of Management and Budget (OMB) under the Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3520). The collections of information in 21 CFR part 312 have been approved under OMB control number 0910-0014; the collections of information in 21 CFR part 600 have been approved under OMB control number 0910-0308; the collections of information in 21 CFR part 601 have been approved under OMB control number 0910-0338; and the collections of information in 21 CFR part 50 have been approved under OMB control number 0910-0755.
Interested persons may submit either electronic comments regarding this document to
Persons with access to the Internet may obtain the guidance at either
Food and Drug Administration, HHS.
Notice.
The Food and Drug Administration (FDA) has determined that the drug products listed in this document were not withdrawn from sale for reasons of safety or effectiveness. This determination means that FDA will not begin procedures to withdraw approval of abbreviated new drug applications (ANDAs) that refer to these drug products, and it will allow FDA to continue to approve ANDAs that refer to the products as long as they meet relevant legal and regulatory requirements.
Stacy Kane, Center for Drug Evaluation and Research, Food and Drug Administration, 10903 New Hampshire Ave. Bldg. 51, Rm. 6207, Silver Spring, MD 20993-0002, 301-796-8363.
In 1984, Congress enacted the Drug Price Competition and Patent Term Restoration Act of 1984 (Pub. L. 98-417) (the 1984 amendments), which authorized the approval of duplicate versions of drug products approved under an ANDA procedure. ANDA sponsors must, with certain exceptions, show that the drug for which they are seeking approval contains the same active ingredient in the same strength and dosage form as the “listed drug,” which is a version of the drug that was previously approved. Sponsors of ANDAs do not have to repeat the extensive clinical testing otherwise necessary to gain approval of a new drug application (NDA).
The 1984 amendments include what is now section 505(j)(7) of the Federal Food, Drug, and Cosmetic Act (21 U.S.C. 355(j)(7)), which requires FDA to publish a list of all approved drugs. FDA publishes this list as part of the “Approved Drug Products With Therapeutic Equivalence Evaluations,” which is generally known as the “Orange Book.” Under FDA regulations, a drug is removed from the list if the Agency withdraws or suspends approval of the drug's NDA or ANDA for reasons of safety or effectiveness, or if FDA determines that the listed drug was withdrawn from sale for reasons of safety or effectiveness (21 CFR 314.162).
Under § 314.161(a) (21 CFR 314.161(a)), the Agency must determine whether a listed drug was withdrawn from sale for reasons of safety or effectiveness: (1) Before an ANDA that refers to that listed drug may be approved, (2) whenever a listed drug is voluntarily withdrawn from sale and ANDAs that refer to the listed drug have been approved, and (3) when a person petitions for such a determination under 21 CFR 10.25(a) and 10.30. Section 314.161(d) provides that if FDA determines that a listed drug was withdrawn from sale for safety or effectiveness reasons, the Agency will initiate proceedings that could result in the withdrawal of approval of the ANDAs that refer to the listed drug.
FDA has become aware that the drug products listed in the table in this document are no longer being marketed.
FDA has reviewed its records and, under § 314.161, has determined that the drug products listed in this document were not withdrawn from sale for reasons of safety or effectiveness. Accordingly, the Agency will continue to list the drug products listed in this document in the “Discontinued Drug Product List” section of the Orange Book. The “Discontinued Drug Product List” identifies, among other items, drug products that have been discontinued from marketing for reasons other than safety or effectiveness.
Approved ANDAs that refer to the NDAs and ANDAs listed in this document are unaffected by the discontinued marketing of the products subject to those NDAs and ANDAs. Additional ANDAs that refer to these products may also be approved by the Agency if they comply with relevant legal and regulatory requirements. If FDA determines that labeling for these drug products should be revised to meet current standards, the Agency will advise ANDA applicants to submit such labeling.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of a meeting of the Board of Scientific Counselors, NIA.
The meeting will be open to the public as indicated below, with attendance limited to space available. Individuals who plan to attend and need special assistance, such as sign language interpretation or other reasonable accommodations, should notify the Contact Person listed below in advance of the meeting.
The meeting will be closed to the public as indicated below in accordance with the provisions set forth in section 552b(c)(6), Title 5 U.S.C., as amended for the review, discussion, and evaluation of individual intramural programs and projects conducted by the NATIONAL INSTITUTE ON AGING, including consideration of personnel qualifications and performance, and the competence of individual investigators, the disclosure of which would constitute a clearly unwarranted invasion of personal privacy.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of the following 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 (5 U.S.C. App.), notice is hereby given of the following meetings.
The meetings will be closed to the public in accordance with the provisions set forth in sections 552b(c)(4) and 552b(c)(6), Title 5 U.S.C., as amended. The grant applications and the discussions could disclose confidential trade secrets or commercial property such as patentable material, and personal information concerning individuals associated with the grant applications, the disclosure of which would constitute a clearly unwarranted invasion of personal privacy.
Notice is hereby given of a change in the meeting of the National Cancer Advisory Board, September 16, 2015, 01:00 p.m. to September 16, 2015, 03:00 p.m., National Cancer Institute Shady Grove, 9609 Medical Center Drive, Rockville, MD, 20850 which was published in the
This meeting is being amended to change the end time of the Open Session on September 16, 2015 from 2:00 p.m. to 1:30 p.m. and the Closed Session time from 2:00 p.m. to 3:30 p.m. to 1:30 p.m. to 3:00 p.m. The meeting is partially Closed to the public.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of the following 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
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of the following 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 (5 U.S.C. App.), notice is hereby given of the following meetings.
The meetings will be closed to the public in accordance with the provisions set forth in sections 552b(c)(4) and 552b(c)(6), Title 5 U.S.C., as amended. The grant applications and the discussions could disclose confidential trade secrets or commercial property such as patentable material, and personal information concerning individuals associated with the grant applications, the disclosure of which would constitute a clearly unwarranted invasion of personal privacy.
Notice is hereby given of a change in the meeting of the Center for Scientific Review Special Emphasis Panel, September 24, 2015, 10:00 a.m. to September 24, 2015, 6:00 p.m., National Institutes of Health, 6701 Rockledge Drive, Bethesda, MD, 20892 which was published in the
The meeting will be held on October 21, 2015. The meeting location and time remain the same. The meeting is closed to the public.
Pursuant to section 10(d) of the Federal Advisory Committee Act, as amended (5 U.S.C. App.), notice is hereby given of a meeting of the NIH Advisory Board for Clinical Research.
The meeting will be open to the public as indicated below, with attendance limited to space available. Individuals who plan to attend and need special assistance, such as sign language interpretation or other reasonable accommodations, should notify the Contact Person listed below in advance of the meeting.
The meeting will be closed to the public in accordance with the provisions set forth in section 552b(c)(9)(B), Title 5 U.S.C., as amended because the premature disclosure of to discuss personnel matters and the discussions would likely to significantly frustrate implementation of recommendations.
Any interested person may file written comments with the committee by forwarding the statement to the Contact Person listed on this notice. The statement should include the name, address, telephone number and when applicable, the business or professional affiliation of the interested person.
In the interest of security, NIH has instituted stringent procedures for entrance onto the NIH campus. All visitor vehicles, including taxicabs, hotel, and airport shuttles will be inspected before being allowed on campus. Visitors will be asked to show one form of identification (for example, a government-issued photo ID, driver's license, or passport) and to state the purpose of their visit.
U.S. Customs and Border Protection, Department of Homeland Security.
General notice.
This document announces U.S. Customs and Border Protection's (CBP's) plan to conduct a National Customs Automation Program (NCAP) test concerning the electronic transmission of certain import data for all Food and Drug Administration (FDA)-regulated commodities. Under the pilot, this data will be transmitted electronically through the Automated Broker Interface (ABI) for processing in CBP's Automated Commercial Environment (ACE) system utilizing the Partnering Government Agency (PGA) Message Set.
The FDA PGA Message Set test will begin no earlier than August 27, 2015. This test will continue until concluded by way of announcement in the
Comments concerning this notice and any aspect of this test may be submitted at any time during the test via email to Josephine Baiamonte, ACE Business Office (ABO), Office of International Trade, at
For PGA-related questions, contact Elizabeth McQueen at
Any party seeking to participate in this test must provide CBP, in its request to participate, its filer code and the port(s) at which it is interested in filing the appropriate PGA Message Set information. At this time, PGA Message Set data may be submitted only for entries filed at certain ports. A current listing of those ports may be found at the following link:
The National Customs Automation Program (NCAP) was established in Subtitle B of Title VI—Customs Modernization (Customs Modernization Act), in the North American Free Trade Agreement Implementation Act, Public Law 103-182, 107 Stat. 2057 (19 U.S.C. 1411). Through NCAP, the initial thrust of customs modernization was on trade compliance and the development of the Automated Commercial Environment (ACE), the planned successor to the Automated Commercial System (ACS). ACE is an automated and electronic system for processing commercial trade data which is intended to streamline business processes, facilitate growth in trade, ensure cargo security, and foster participation in global commerce, while
CBP's modernization efforts are accomplished through phased releases of ACE component functionality designed to replace specific legacy ACS functions. Each release will begin with a test and will end with mandatory use of the new ACE feature, thus retiring the legacy ACS function. Each release builds on previous releases and sets the foundation for subsequent releases.
For the convenience of the public, a chronological listing of
The Customs Modernization Act provisions provide the Commissioner of CBP with authority to conduct limited test programs or procedures designed to evaluate planned components of the NCAP. The test described in this notice is authorized pursuant to § 101.9(b) of title 19 of the Code of Federal Regulations (19 CFR 101.9(b)) which provides for the testing of NCAP programs or procedures.
This test is also in furtherance of the International Trade Data System (ITDS) key initiatives, set forth in section 405 of the Security and Accountability for Every Port Act of 2006 (“SAFE Port Act”), Sec. 405, Public Law 109-347, 120 Stat. 1884 (19 U.S.C. 1411(d)) and in Executive Order 13659 of February 19, 2014,
Executive Order 13659 requires that by December 31, 2016, ACE, as the ITDS single window, have the operational capabilities to serve as the primary means of receiving from users the standard set of data and other relevant documentation (exclusive of applications for permits, licenses, or certifications) required for the release of imported cargo and clearance of cargo for export, and to transition from paper-based requirements and procedures to faster and more cost-effective electronic submissions to, and communications with, U.S. government agencies.
The PGA Message Set is the data needed to satisfy the PGA reporting requirements. ACE enables the message set by acting as the “single window” for the submission of trade-related data required by the PGAs only once to CBP. Once validated, the data will be made available to the relevant PGAs involved in import, export, and transportation-related decision making. The data will be used to fulfill merchandise entry requirements and may allow for earlier release decisions and more certainty for the importer in determining the logistics of cargo delivery. Also, by virtue of being electronic, the PGA Message Set will eliminate the necessity for the submission and subsequent handling of paper documents.
At this time, a limited number of ports of entry will be accepting FDA PGA Message Set data. A list of those ports is provided at the following link:
Section 801 of the Federal Food, Drug, and Cosmetic Act (FD&C Act) (21 U.S.C. 381) authorizes the Secretary of Health and Human Services (HHS), through the FDA, to make admissibility decisions for FDA-regulated commodities (foods, drugs, cosmetics, medical devices, and tobacco products), and prior notice risk and threat assessment decisions for imported food products. Moreover, section 536 of the FD&C Act (21 U.S.C. 360mm) and 42 U.S.C. 264 provide similar authority for radiation emitting products and human cell, tissue, and cellular and tissue-based products (HCT/Ps). Carrying out these responsibilities involves close coordination and cooperation between the FDA and CBP.
Until October 1998, importers were required to file manual entries on Office of Management and Budget (OMB)-approved forms which were accompanied by related documents. Thereafter, the FDA implemented an automated nationwide entry processing system known as the “Operational and Administrative System for Import Support (OASIS)” that enabled the FDA to more efficiently obtain and process the information it requires to fulfill its regulatory responsibilities. Most of the data that the FDA requires to make admissibility and prior notice-related decisions regarding imported products is already provided electronically by importers and entry filers to CBP. Since CBP relays the entry data to the FDA using an electronic interface as discussed below, most of the data submitted by an importer or entry filer need be completed only once.
Information for commercial entries for shipments of FDA-regulated products that are imported or offered for import into the United States is submitted by the importer (or his or her agent) or entry filer through CBP's Automated Broker Interface of the Automated Commercial System (ABI/ACS) into OASIS. For imported foods and feeds, this process includes the submission of prior notice information, which is reviewed for targeting higher-risk shipments for examination by the FDA or CBP upon arrival at the port of entry. With respect to the transmission of entry information, the FDA reviews relevant data as part of its admissibility review. The FDA sends a message back to the importer or entry filer with its decision as to whether (1) the product is admissible; (2) additional information is required; (3) an examination of the shipment is required; or (4) the shipment is subject to refusal of admission.
In December of 2011, the FDA fully implemented its new admissibility targeting application called “Predictive Risk-based Evaluation for Dynamic Import Compliance Targeting,” commonly known as “PREDICT.” PREDICT screens all entries, identifies shipments based on risk, and facilitates FDA's ability to determine whether products should be examined or
In addition to the entry information collected by CBP, the FDA uses additional data elements in order to make an admissibility decision. This information includes the following data elements:
(1) FDA product code;
(2) FDA country of production;
(3) FDA-required information on the manufacturer and shipper; and
(4) Ultimate consignee.
Additionally, the FDA has identified data elements or Affirmation of Compliance (“A of C”) codes that an importer or entry filer may submit upon entry to help expedite the review process. For example, providing the registration number of the manufacture as an A of C may result in an immediate release of the product. Alternatively, an entry filed without the A of C code would be flagged for review and release may be delayed.
If the FDA did not collect this data the agency could not adequately meet its statutory responsibilities to regulate imported products, nor control potentially dangerous products from entering the U.S. marketplace.
This document announces CBP's plan to conduct a new test pilot concerning the submission of electronic FDA data elements required by the FDA's cargo admissibility process under the auspices of ACE for those commodities regulated by the FDA that are being imported or offered for import into the United States. This new FDA PGA Message Set capability will satisfy the FDA data requirements for formal and informal consumption entries through electronic filing in ACE and via the FDA PGA Message Set. This will enable the trade community to have a CBP-managed “single window” for the submission of data required by the FDA during the cargo importation and review process. For FDA-regulated food products requiring prior notice, the necessary PGA data elements must be submitted prior to the time of arrival of the merchandise. The technical requirements for submitting FDA data elements are set forth in the supplemental Customs and Trade Automated Interface Requirements (CATAIR) guidelines for the FDA. These technical requirements, including the ACE CATAIR chapters, can be found at the following link:
Upon successful completion of the FDA PGA Message Set test, it is anticipated that CBP will decommission the legacy ACS/OASIS interface for the new ACE/OASIS interface.
PGA Message Set test participants will be required to:
(1) Transmit the appropriate ACE PGA Message Set data, including the additional data elements listed in Section V of this notice, for the commodities and the ports of entry based upon the implementation schedule found at the following link:
(2) Transmit the PGA Message Set electronically to ACE using ACE Entry or ACE Entry Summary at any time prior to the arrival of the merchandise on the conveyance transporting the cargo to the United States;
(3) Transmit PGA Message Set import filings only as part of an ACE Entry or ACE Entry Summary certified for cargo release;
(4) Transmit import entry filings to CBP via ABI in response to a request for documentation or in response to a request for release information for certified ACE Entry Summaries;
(5) Only transmit to CBP information that has been requested by either CBP or the FDA;
(6) Use a software program that has completed ACE certification testing for the PGA Message Set; and
(7) Take part in a CBP-FDA evaluation of this test.
For purposes of this test, those provisions of 19 CFR part 12 that are inconsistent with the terms of this test are waived for test participants only. See 19 CFR 101.9(b). This document does not waive any recordkeeping requirements found in part 163 of title 19 of the Code of Federal Regulations (19 CFR part 163) and the Appendix to part 163 (commonly known as the “(a)(1)(A) list”).
To be eligible to apply for this test, the applicant must:
(1) Be a self-filing importer who has the ability to file ACE Entry Summaries certified for cargo release or a broker who has the ability to file ACE Entry Summaries certified for cargo release; and
(2) File prior notices or entries for FDA-regulated commodities.
Test participants must meet all the eligibility criteria described in this document in order to participate in the test program.
Any party seeking to participate in the FDA PGA Message Set test should email their CBP Client Representative, ACE Business Office (ABO), Office of International Trade. Interested parties without an assigned client representative should submit an email message to Steven Zaccaro at
Email messages sent to the CBP client representative or Steven Zaccaro must include the applicant's filer code and the port(s) at which it is interested in filing the appropriate PGA Message Set information. Client representatives will work with test participants to provide information regarding the transmission of this data.
CBP will begin to accept applications upon the date of publication of this notice and will continue to accept applications throughout the duration of the test. CBP will notify the selected applicants by an email message of their selection and the starting date of their participation. Selected participants may have different starting dates. Anyone providing incomplete information, or otherwise not meeting participation requirements, will be notified by an email message and given the opportunity to resubmit its application.
The initial phase of the pilot test will begin no earlier than August 27, 2015. At the conclusion of the test pilot, an evaluation will be conducted to assess the effect that the FDA PGA Message Set has on expediting the submission of FDA importation-related data elements and the processing of FDA entries. The final results of the evaluation will be published in the
All interested parties are invited to comment on any aspect of this test at any time. CBP requests comments and
The collection of information contained in this FDA PGA Message Set test has been approved by the Office of Management and Budget (OMB) in accordance with the requirements of the Paperwork Reduction Act (44 U.S.C. 3507) and assigned OMB control number 0910-0046. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a valid control number assigned by OMB.
Data submitted and entered into the ACE Portal includes information that is exempt or restricted from disclosure by law, such as by the Trade Secrets Act (18 U.S.C. 1905). As stated in previous notices, participation in this or any of the previous ACE tests is not confidential and upon a written Freedom of Information Act (FOIA) request, a name(s) of an approved participant(s) will be disclosed by CBP in accordance with 5 U.S.C. 552.
A test participant may be subject to civil and criminal penalties, administrative sanctions, liquidated damages, or discontinuance from participation in this test for any of the following:
(1) Failure to follow the terms and conditions of this test;
(2) Failure to exercise reasonable care in the execution of participant obligations;
(3) Failure to abide by applicable laws and regulations that have not been waived; or
(4) Failure to deposit duties or fees in a timely manner.
If the Director, Business Transformation, ACE Business Office (ABO), Office of International Trade, finds that there is a basis for discontinuance of test participation privileges, the test participant will be provided a written notice proposing the discontinuance with a description of the facts or conduct warranting the action. The test participant will be offered the opportunity to appeal the Director's decision in writing within 10 calendar days of receipt of the written notice. The appeal must be submitted to Acting Executive Director, ABO, Office of International Trade, by emailing
The Acting Executive Director will issue a decision in writing on the proposed action within 30 working days after receiving a timely filed appeal from the test participant. If no timely appeal is received, the proposed notice becomes the final decision of the Agency as of the date that the appeal period expires. A proposed discontinuance of a test participant's privileges will not take effect unless the appeal process under this paragraph has been concluded with a written decision adverse to the test participant.
In the case of willfulness or those in which public health, interest, or safety so requires, the Director, Business Transformation, ABO, Office of International Trade, may immediately discontinue the test participant's privileges upon written notice to the test participant. The notice will contain a description of the facts or conduct warranting the immediate action. The test participant will be offered the opportunity to appeal the Director's decision within 10 calendar days of receipt of the written notice providing for immediate discontinuance. The appeal must be submitted to Acting Executive Director, ABO, Office of International Trade, by emailing
A chronological listing of
• ACE Portal Accounts and Subsequent Revision Notices: 67 FR 21800 (May 1, 2002); 69
• ACE System of Records Notice: 71 FR 3109 (January 19, 2006).
• Terms/Conditions for Access to the ACE Portal and Subsequent Revisions: 72 FR 27632 (May 16, 2007); 73 FR 38464 (July 7, 2008).
• ACE Non-Portal Accounts and Related Notice: 70 FR 61466 (October 24, 2005); 71 FR 15756 (March 29, 2006).
• ACE Entry Summary, Accounts and Revenue (ESAR I) Capabilities: 72 FR 59105 (October 18, 2007).
• ACE Entry Summary, Accounts and Revenue (ESAR II) Capabilities: 73 FR 50337 (August 26, 2008); 74 FR 9826 (March 6, 2009).
• ACE Entry Summary, Accounts and Revenue (ESAR III) Capabilities: 74 FR 69129 (December 30, 2009).
• ACE Entry Summary, Accounts and Revenue (ESAR IV) Capabilities: 76 FR 37136 (June 24, 2011).
• Post-Entry Amendment (PEA) Processing Test: 76 FR 37136 (June 24, 2011).
• ACE Announcement of a New Start Date for the National Customs Automation Program Test of Automated Manifest Capabilities for Ocean and Rail Carriers: 76 FR 42721 (July 19, 2011).
• ACE Simplified Entry: 76 FR 69755 (November 9, 2011).
• National Customs Automation Program (NCAP) Tests Concerning Automated Commercial Environment (ACE) Document Image System (DIS): 77 FR 20835 (April 6, 2012).
• National Customs Automation Program (NCAP) Tests Concerning Automated Commercial Environment (ACE) Simplified Entry: Modification of Participant Selection Criteria and Application Process: 77 FR 48527 (August 14, 2012).
• Modification of NCAP Test Regarding Reconciliation for Filing Certain Post-Importation Preferential Tariff Treatment Claims under Certain FTAs: 78 FR 27984 (May 13, 2013).
• Modification of Two National Customs Automation Program (NCAP) Tests Concerning Automated Commercial Environment (ACE) Document Image System (DIS) and Simplified Entry (SE): 78 FR 44142 (July 23, 2013).
• Modification of Two National Customs Automation Program (NCAP) Tests Concerning Automated Commercial Environment (ACE) Document Image System (DIS) and Simplified Entry (SE); Correction: 78 FR 53466 (August 29, 2013).
• Modification of NCAP Test Concerning Automated Commercial Environment (ACE) Cargo Release (formerly known as Simplified Entry): 78 FR 66039 (November 4, 2013).
• Post-Summary Corrections to Entry Summaries Filed in ACE Pursuant to the ESAR IV Test: Modifications and Clarifications: 78 FR 69434 (November 19, 2013).
• National Customs Automation Program (NCAP) Test Concerning the Submission of Certain Data Required by the Environmental Protection Agency and the Food Safety and Inspection Service Using the Partner Government Agency Message Set Through the Automated Commercial Environment (ACE): 78 FR 75931 (December 13, 2013).
• Modification of National Customs Automation Program (NCAP) Test Concerning Automated Commercial Environment (ACE) Cargo Release for Ocean and Rail Carriers: 79 FR 6210 (February 3, 2014).
• Modification of National Customs Automation Program (NCAP) Test Concerning Automated Commercial Environment (ACE) Cargo Release to Allow Importers and Brokers to Certify From ACE Entry Summary: 79 FR 24744 (May 1, 2014).
• Modification of National Customs Automation Program (NCAP) Test Concerning Automated Commercial Environment (ACE) Cargo Release for Truck Carriers: 79 FR 25142 (May 2, 2014).
• Modification of National Customs Automation Program (NCAP) Test Concerning Automated Commercial Environment (ACE) Document Image System: 79 FR 36083 (June 25, 2014).
• Announcement of eBond Test: 79 FR 70881 (November 28, 2014).
• eBond Test Modifications and Clarifications: Continuous Bond Executed Prior to or Outside the eBond Test May Be Converted to an eBond by the Surety and Principal, Termination of an eBond by Filing Identification Number, and Email Address Correction: 80 FR 899 (January 7, 2015).
• Modification of National Customs Automation Program (NCAP) Test Concerning Automated Commercial Environment (ACE) Document Image System Relating to Animal and Plant Health Inspection Service (APHIS) Document Submissions: 80 FR 5126 (January 30, 2015).
• Modification of National Customs Automation Program (NCAP) Test Concerning the use of Partner Government Agency Message Set through the Automated Commercial Environment (ACE) for the Submission of Certain Data Required by the Environmental Protection Agency (EPA): 80 FR 6098 (February 4, 2015).
• Announcement of Modification of ACE Cargo Release Test to Permit the Combined Filing of Cargo Release and Importer Security Filing (ISF) Data: 80 FR 7487 (February 10, 2015).
• Modification of NCAP Test Concerning ACE Cargo Release for Type 03 Entries and Advanced Capabilities for Truck Carriers: 80 FR 16414 (March 27, 2015).
• Automated Commercial Environment (ACE) Export Manifest for Air Cargo Test: 80 FR 39790 (July 10, 2015).
• National Customs Automation Program (NCAP) Concerning Remote Location Filing Entry Procedures in the Automated Commercial Environment (ACE) and the Use of the Document Image System for the Submission of Invoices and the Use of eBonds for the Transmission of Single Transaction Bonds: 80 FR 40079 (July 13, 2015).
Fish and Wildlife Service, Interior.
Notice; request for comments.
We (U.S. Fish and Wildlife Service) have sent an Information Collection Request (ICR) to OMB for review and approval. We summarize the ICR below and describe the nature of the collection and the estimated burden and cost. This information collection is scheduled to expire on August 31, 2015. We 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. However, under OMB regulations, we may continue to conduct or sponsor this information collection while it is pending at OMB.
You must submit comments on or before September 28, 2015.
Send your comments and suggestions on this information collection to the Desk Officer for the Department of the Interior at OMB-OIRA at (202) 395-5806 (fax) or
To request additional information about this ICR, contact Hope Grey at
The Policy for Evaluation of Conservation Efforts When Making Listing Decisions (PECE) (68 FR 15100, March 28, 2003) encourages the development of conservation agreements/plans and provides certainty about the standard that an individual conservation effort must meet in order for us to consider whether it contributes to forming a basis for making a decision about the listing of a species. PECE applies to “formalized conservation efforts” that have not been implemented or have been implemented but have not yet demonstrated if they are effective at the time of a listing decision.
Under PECE, formalized conservation efforts are defined as conservation efforts (specific actions, activities, or programs designed to eliminate or reduce threats or otherwise improve the status of a species) identified in a conservation agreement, conservation plan, management plan, or similar document. To assist us in evaluating a formalized conservation effort under PECE, we collect information such as conservation plans, monitoring results, and progress reports. The development of such agreements/plans is voluntary. There is no requirement that the individual conservation efforts included in such documents be designed to meet the standard in PECE. The PECE policy is posted on our Candidate Conservation Web site at
We again invite comments concerning this information collection on:
• Whether or not the collection of information is necessary, including whether or not the information will have practical utility;
• The accuracy of our estimate of the burden for this collection of information;
• 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 on respondents.
Comments that you submit in response to this notice are a matter of public record. 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 OMB in your comment to withhold your personal identifying information from public review, we cannot guarantee that it will be done.
Fish and Wildlife Service, Interior.
Notice of availability; final environmental impact statement.
We, the U.S. Fish and Wildlife Service, announce the availability of a final environmental impact statement (EIS) for the comprehensive conservation plan (CCP) for the Rocky Mountain Arsenal National Wildlife Refuge (refuge) in Adams County, Colorado. In the final environmental impact Statement we describe alternatives, including our preferred alternative, to manage the refuge for the 15 years following approval of the final CCP.
You may request copies or more information by one of the following methods. You may request hard copies or a CD-ROM of the documents.
To view comments on the final CCP-EIS from the Environmental Protection Agency (EPA), or for information on EPA's role in the EIS process, see EPA's Role in the EIS Process under
Bernardo Garza, Planning Team Leader, 303-236-4377 (phone) or
With this notice, we announce the availability of the final EIS for the refuge. We started this process through a notice in the
The EPA is charged under section 309 of the Clean Air Act to review all Federal agencies' EISs and to comment on the adequacy and the acceptability of the environmental impacts of proposed actions in the EISs.
EPA also serves as the repository (EIS database) for EISs prepared by Federal agencies and provides notice of their availability in the
The notice of availability is the start of the 45-day public comment period for draft EISs, and the start of the 30-day “wait period” for final EISs, during which agencies are generally required to wait 30 days before making a decision on a proposed action. For more
In 1992 Congress passed the act that established the refuge to (1) conserve and enhance populations of fish, wildlife, and plants within the refuge, including populations of waterfowl, raptors, passerines, and marsh and water birds; (2) conserve species listed as threatened or endangered under the Endangered Species Act and species that are candidates for such listing; (3) provide maximum fish and wildlife-oriented public uses at levels compatible with the conservation and enhancement of wildlife and wildlife habitat; (4) provide opportunities for compatible scientific research; (5) provide opportunities for compatible environmental and land use education; (6) conserve and enhance the land and water of the refuge in a manner that will conserve and enhance the natural diversity of fish, wildlife, plants, and their habitats; (7) protect and enhance the quality of aquatic habitat within the refuge; and (8) fulfill international treaty obligations of the United States with respect to fish and wildlife and their habitats. The refuge is surrounded by the cities of Commerce City and Denver, along the Colorado Front Range. It encompasses nearly 16,000 acres and is home to more than 468 plant species and 350 wildlife species, including bison, deer, a wide variety of resident and migratory birds and raptors, amphibians, reptiles, fishes, and insects. The refuge's habitats include short and mixed grass prairie, interspersed with native shrubs, riparian corridors, lacustrine habitats on the refuge reservoirs, and woodlands planted by settlers around historic homesteads.
The National Wildlife Refuge System Administration Act of 1966, as amended (16 U.S.C. 668dd-668ee) (Administration Act) by the National Wildlife Refuge System Improvement Act of 1997, requires us to develop a CCP for each national wildlife refuge. The purpose for developing a CCP is to provide refuge managers with a 15-year plan for achieving refuge purposes and contributing toward the mission of the National Wildlife Refuge System (NWRS), consistent with sound principles of fish and wildlife management, conservation, legal mandates, and our policies. In addition to outlining broad management direction on conserving wildlife and their habitats, CCPs identify wildlife-dependent recreational opportunities available to the public, including, where appropriate, opportunities for hunting, fishing, wildlife observation and photography, and environmental education and interpretation. We will review and update the CCP at least every 15 years as necessary in accordance with the Administration Act.
We started the public outreach process in June 2013. At that time and throughout the process, we requested public comments and considered them in numerous ways. Public outreach has included holding eight public meetings, mailing planning updates, maintaining a project Web site, and publishing press releases. We have considered and evaluated all the comments we have received throughout this process.
During the public scoping process with which we started work on the draft CCP and draft EIS, we, our Federal and State partners, and the public identified several issues. Our final EIS addresses both the scoping comments and the comments we received on the draft CCP and draft EIS. A full description of each alternative is in the final EIS. Alternative C, Urban Refuge, was selected as the preferred alternative. To address these issues, we developed and evaluated the following alternatives, summarized below.
Alternative A is the no-action alternative, which represents the current management of the refuge. This alternative provides the baseline against which to compare the other alternatives. Under this alternative, management activity conducted by the Service would remain the same. The Service would not develop any new management, restoration, or education programs at the refuge. Current habitat and wildlife practices would not be expanded or changed. Funding and staff levels would remain the same, with little change in overall trends. Programs would follow the same direction, emphasis, and intensity as they do now. We would continue implementing the habitat restoration and management objectives set in the refuge's habitat management plan and other approved plans to provide for a wide variety of resident and migratory species.
This alternative focuses on providing traditional refuge visitor uses and conveying the importance of conservation, wildlife protection, and the purposes of the Refuge System. Access to the refuge would remain more limited than in alternatives C and D. Wildlife-dependent recreation and community outreach would be minimally expanded. We would continue to manage the refuge's habitat and wildlife as in Alternative A, and would reintroduce to the refuge black-footed ferrets, and self-sustaining populations of greater prairie-chicken and sharp-tailed grouse. We would maintain the same levels of access and transportation as under Alternative A, but would enhance the main refuge entrance, improve visitor services facilities, and seek to improve trail accessibility.
The emphasis of this alternative is to increase the visibility of the refuge within the Denver metropolitan area and to welcome many more nontraditional visitors to the refuge. Through an expanded visitor services program, an abundance of instructional programming, and widespread outreach, we would endeavor to connect more people with nature and wildlife. In this alternative, the refuge would be made more accessible to outlying communities with the opening of additional access points and the development of enhanced transportation system. We would work with nontraditional users' trusted avenues of communication to increase outreach success. We would expand our conservation education in surrounding communities and schools, develop youth-specific outreach, and employ social marketing to broaden our agency's reach. We would manage the refuge's habitat and wildlife as in Alternative B, but the reintroduction of greater prairie-chicken and sharp-tailed grouse would be attempted regardless of whether these species' populations are likely to become self-sustaining.
The emphasis of this alternative is to work with partners to increase the visibility of the refuge, the Refuge System, and other public lands in the area. There will be less visitor services programming at the refuge and efforts to engage with the public will be extended to off-site locations. We would work with Denver International Airport to improve physical connections between
We solicited comments on the draft CCP and draft EIS from May 6, 2015, through July 6, 2015. During the comment period, we thoroughly evaluated and considered all the comments we received verbally or via letters, email, and electronic forms from the public. Our responses to comments are included in the final EIS.
We made the following changes in the final EIS from the draft CCP and draft EIS:
• Several comments pointed out the need to increase the number of law enforcement officers in the refuge to better cope with the increased visitation and new access to the refuge. Thus the Final EIS reflects our desire to seek more than one full-time law enforcement officer for the refuge under Alternatives C and D.
• As necessary, we updated maps, corrected errors, and provided additional clarification throughout the final EIS.
In addition to any one method in
• Our Web site:
• Public libraries:
We will document the final decision in a record of decision, which will be published in the
Bureau of Land Management, Interior.
Notice.
The purpose of this notice is to inform the public and interested State and local government officials of the filing of Plats of Survey in Nevada.
Unless otherwise stated filing is effective at 10:00 a.m. on the dates indicated below.
Michael O. Harmening, Chief, Branch of Geographic Sciences, Bureau of Land Management, Nevada State Office, 1340 Financial Blvd., Reno, NV 89502-7147, phone: 775-861-6490. Persons who use a telecommunications device for the deaf (TDD) may call the Federal Information Relay Service (FIRS) at 1-800-877-8339 to contact the above individual during normal business hours. The FIRS is available 24 hours a day, 7 days a week, to leave a message or question with the above individual. You will receive a reply during normal business hours.
1. The Plat of Survey of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on April 17, 2015.
The plat, in 2 sheets, representing the dependent resurvey of a portion of the north boundary and a portion of the subdivisional lines, the subdivision of section 2 and metes-and-bounds surveys in section 2, Township 4 South, Range 60 East, of the Mount Diablo Meridian, Nevada, under Group No. 914, was accepted April 16, 2015. This survey was executed to meet certain administrative needs of the Bureau of Land Management.
2. The Plat of Survey of the following described lands was officially filed at the Bureau of Land Management (BLM) Nevada State Office, Reno, Nevada on June 4, 2015:
The plat, in 1 sheet, representing the dependent resurvey of a portion of the south boundary and a portion of the subdivisional lines, the subdivision of sections 35 and 36, and a metes-and-bounds survey of the centerline of Nevada State Route 318 through a portion of section 35, Township 3 South, Range 60 East, Mount Diablo Meridian, Nevada, under Group No. 929, was accepted June 2, 2015. This survey was executed to meet certain administrative needs of the Bureau of Land Management.
3. The Plat of Survey of the following described lands was officially filed at the Bureau of Land Management (BLM) Nevada State Office, Reno, Nevada on June 4, 2015:
The plat, in 1 sheet, representing the dependent resurvey of a portion of the east boundary, a portion of the north boundary and a portion of the subdivisional lines, and the subdivision of section 1, Township 4 South, Range 60 East, Mount Diablo Meridian, Nevada, under Group No. 929, was accepted June 2, 2015. This survey was executed to meet certain administrative needs of the Bureau of Land Management.
4. The Plat of Survey of the following described lands was officially filed at the Bureau of Land Management (BLM) Nevada State Office, Reno, Nevada on June 25, 2015:
The plat, in 3 sheets, representing the dependent resurvey of a portion of the south boundary, a portion of the subdivisional lines, and portions of Mineral Survey Nos. 4892 and 4893, and a metes-and-bounds survey in sections 35 and 36, Township 13 North, Range 26 East, Mount Diablo Meridian, Nevada, under Group No. 941, was accepted June 12, 2015. This survey was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
5. The Plat of Survey of the following described lands was officially filed at
The plat, in 2 sheets, representing the dependent resurvey of a portion of the north boundary, a portion of the subdivisional lines, and the subdivision of sections 3 and 4, Township 34 North, Range 55 East, Mount Diablo Meridian, Nevada, under Group No. 942, was accepted June 29, 2015. This survey was executed to define and mark boundaries for management of the Te-Moak trust lands transferred by legislation, as authorized by Public Law 113-291.
6. The Plat of Survey of the following described lands was officially filed at the Bureau of Land Management (BLM) Nevada State Office, Reno, Nevada on July 24, 2015:
The plat, in 2 sheets, representing the dependent resurvey of a portion of the east boundary, a portion of the subdivisional lines, and the subdivision of section 25, and certain metes-and-bounds surveys in section 25, Township 34 North, Range 54 East, Mount Diablo Meridian, Nevada, under Group No. 943, was accepted July 22, 2015. This survey was executed to facilitate the conveyance of certain public lands, as authorized by Public Law 113-291.
7. The Plat of Survey of the following described lands was officially filed at the Bureau of Land Management (BLM) Nevada State Office, Reno, Nevada on July 24, 2015:
The plat, in 1 sheet, representing the dependent resurvey of a portion of the east boundary, and a metes-and-bounds survey in section 25, Township 34 North, Range 54 1/2 East, Mount Diablo Meridian, Nevada, under Group No. 943, was accepted July 22, 2015. This survey was executed to facilitate the conveyance of certain public lands, as authorize by Public Law 113-291.
8. The Plat of Survey of the following described lands was officially filed at the Bureau of Land Management (BLM) Nevada State Office, Reno, Nevada on July 30, 2015:
The plat, in 1 sheet, representing the dependent resurvey of Mineral Survey Nos. 3962 and 3971, in unsurveyed Township 5 South, Range 46 East, Mount Diablo Meridian, Nevada, under Group No. 946, was accepted July 29, 2015. This survey was executed to identify the boundaries of certain mineral surveys to the extent necessary to identify federal interest for eventual conveyance to the United States.
9. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 4, 2015: The supplemental plat, in 1 sheet, showing amended lottings in section 17, Township 19 South, Range 60 East, of the Mount Diablo Meridian, Nevada, under Group No. 947, was accepted June 3, 2015. This supplemental plat was prepared to meet certain administrative needs of the Bureau of Land Management.
10. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 25, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 2, Township 12 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 951, was accepted June 22, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
11. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 25, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 3, Township 12 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 951, was accepted June 22, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
12. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 25, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 4, Township 12 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 951, was accepted June 22, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
13. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 25, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 9, Township 12 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 951, was accepted June 22, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
14. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 25, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 10, Township 12 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 951, was accepted June 22, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
15. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on June 25, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 11, Township 12 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 951, was accepted June 22, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
16. The Supplemental Plat of the following described lands was officially filed at the BLM Nevada State Office, Reno, Nevada on August 11, 2015:
The supplemental plat, in 1 sheet, showing amended lottings in section 33, Township 13 North, Range 26 East, of the Mount Diablo Meridian, Nevada, under Group No. 953, was accepted August 11, 2015. This supplemental plat was executed to facilitate the conveyance of certain public land to the municipality of Yerington, Nevada, as authorized by Public Law 113-291.
The surveys and supplemental plats listed above are now the basic record for describing the lands for all authorized purposes. These records have been placed in the open files in the BLM Nevada State Office and are available to the public as a matter of information. Copies of the surveys and related field notes may be furnished to the public upon payment of the appropriate fees.
Bureau of Land Management, Interior.
Notice of public meeting.
In accordance with the Federal Land Policy and Management
The RAC will meet on October 15, 2015, at the Carlsbad Field Office, 620 East Greene Street, Carlsbad, New Mexico, from 9 a.m.-4 p.m. The public may send written comments to the RAC at the BLM Pecos District, 2909 West 2nd Street, Roswell, New Mexico, 88201.
Howard Parman, Pecos District Office, Bureau of Land Management, 2909 West 2nd Street, Roswell, New Mexico 88201, 575-627-0212. Persons who use a telecommunications device for the deaf (TDD) may call the Federal Information Relay Service (FIRS) at 1-800-877-8229 to contact the above individual during normal business hours. The FIRS is available 24 hours a day, 7 days a week, to leave a message or question with the above individual. You will receive a reply during normal business hours.
The 10-member Pecos District RAC advises the Secretary of the Interior, through the BLM, on a variety of planning and management issues associated with public land management in the BLM's Pecos District. Planned agenda items include: Election of a new chairman; report on the status of the Carlsbad plan revision; an overview of penalties for non-compliance for oil and gas development activities; presentations by both BLM staff and cave interests regarding the BLM's management of caves in regards to containing the spread of white nose syndrome; and a field trip to the Delaware and Black Rivers to discuss issues associated with these bodies of water.
All RAC meetings are open to the public. There will be a half-hour public comment period at 9:30 a.m. for any interested members of the public who wish to address the RAC. Depending on the number of persons wishing to speak and time available, the time for individual comments may be limited.
Bureau of Land Management, Interior.
Notice.
The plats of survey of the following described lands are scheduled to be officially filed in the Bureau of Land Management, Oregon State Office, Portland, Oregon, 30 days from the date of this publication.
A copy of the plats may be obtained from the Public Room at the Bureau of Land Management, Oregon State Office, 1220 SW. 3rd Avenue, Portland, Oregon 97204, upon required payment.
Kyle Hensley, (503) 808-6132, Branch of Geographic Sciences, Bureau of Land Management, 1220 SW. 3rd Avenue, Portland, Oregon 97204. Persons who use a telecommunications device for the deaf (TDD) may call the Federal Information Relay Service (FIRS) at 1-800-877-8339 to contact the above individual during normal business hours. The FIRS is available 24 hours a day, 7 days a week, to leave a message or question with the above individual. You will receive a reply during normal business hours.
A person or party who wishes to protest against this survey must file a written notice with the Oregon State Director, Bureau of Land Management, stating that they wish to protest. A statement of reasons for a protest may be filed with the notice of protest and must be filed with the Oregon State Director within thirty days after the protest is filed. If a protest against the survey is received prior to the date of official filing, the filing will be stayed pending consideration of the protest. A plat will not be officially filed until the day after all protests have been dismissed or otherwise resolved. 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.
Bureau of Land Management, Interior.
Notice of public meeting.
In accordance with the Federal Land Policy and Management Act (FLPMA) and the Federal Advisory Committee Act of 1972 (FACA), the U.S. Department of the Interior, Bureau of Land Management (BLM) Central Montana Resource Advisory Council (RAC) will meet as indicated below.
The Central Montana Resource Advisory Council Meeting will be held October 6-7, 2015 in Chinook, Montana. The October 6 meeting will begin at 10:00 a.m. with a 30-minute public comment period and will adjourn at 5:00 p.m. The October 7 meeting will begin at 8:00 a.m. with a 30-minute public comment period beginning at 10:00 a.m. and will adjourn at 12:00 p.m.
The meetings will be in the Chinook Motor Inn Conference Room at 100 Indian Street, Chinook, Montana.
Mark Albers, HiLine District Manager, Great Falls Field Office, 1101 15th Street North, Great Falls, MT 59401, (406) 791-7789,
This 15-member council advises the Secretary of the Interior, through the BLM, on a variety of management issues associated with public land management in Montana. During these meetings the
Each formal RAC meeting will also have time allocated for hearing public comments. Depending on the number of persons wishing to comment and time available, the time for individual oral comments may be limited.
43 CFR 1784.4-2.
60-day Notice.
To comply with the Paperwork Reduction Act of 1995 (PRA), BSEE is inviting comments on a collection of information that we will submit to the Office of Management and Budget (OMB) for review and approval. The information collection request (ICR) concerns a renewal to the paperwork requirements in the regulations under Subpart K,
You must submit comments by October 26, 2015.
You may submit comments by either of the following methods listed below.
• Electronically go to
• Email
Cheryl Blundon, Regulations and Standards Branch at (703) 787-1607 to request additional information about this ICR.
Section 5(a) of the OCS Lands Act requires the Secretary to prescribe rules and regulations “to provide for the prevention of waste, and conservation of the natural resources of the Outer Continental Shelf, and the protection of correlative rights therein” and to include provisions “for the prompt and efficient exploration and development of a lease area.”
Section 1334(g)(2) states “. . . the lessee shall produce such oil or gas, or both, at rates . . . to assure the maximum rate of production which may be sustained without loss of ultimate recovery of oil or gas, or both, under sound engineering and economic principles, and which is safe for the duration of the activity covered by the approved plan.”
In addition to the general rulemaking authority of the OCSLA at 43 U.S.C. 1334, section 301(a) of the Federal Oil and Gas Royalty Management Act (FOGRMA), 30 U.S.C. 1751(a), grants authority to the Secretary to prescribe such rules and regulations as are reasonably necessary to carry out FOGRMA's provisions. While the majority of FOGRMA is directed to royalty collection and enforcement, some provisions apply to offshore operations. For example, section 108 of FOGRMA, 30 U.S.C. 1718, grants the Secretary broad authority to inspect lease sites for the purpose of determining whether there is compliance with the mineral leasing laws. Section 109(c)(2) and (d)(1), 30 U.S.C. 1719(c)(2) and (d)(1), impose substantial civil penalties for failure to permit lawful inspections and for knowing or willful preparation or submission of false, inaccurate, or misleading reports, records, or other information. Because the Secretary has delegated some of the authority under FOGRMA to BSEE, 30 U.S.C. 1751 is included as additional authority for these requirements.
The Independent Offices Appropriations Act (31 U.S.C. 9701), the Omnibus Appropriations Bill (Pub. L. 104-133, 110 Stat. 1321, April 26, 1996), and OMB Circular A-25, authorize Federal agencies to recover the full cost of services that confer special benefits. Under the Department of the Interior's implementing policy, the Bureau of Safety and Environmental Enforcement (BSEE) is required to charge the full cost for services that provide special benefits or privileges to an identifiable non-Federal recipient above and beyond those that accrue to the public at large. Several requests for approval required in Subpart K are subject to cost recovery, and BSEE regulations specify service fees for these requests.
Regulations implementing these responsibilities are among those delegated to BSEE. The regulations under 30 CFR 250, subpart K, pertain to governing oil and gas production, associated forms, and related Notices to Lessees (NTLs) and Operators. BSEE issued several NTLs to clarify and provide additional guidance on some aspects of the current subpart K regulations.
We use the information in our efforts to conserve natural resources, prevent waste, and protect correlative rights, including the Government's royalty interest. Specifically, BSEE uses the information to:
• Evaluate requests to burn liquid hydrocarbons and vent and flare gas to ensure that these requests are appropriate;
• determine if a maximum production or efficient rate is required; and,
• review applications for downhole commingling to ensure that action does not result in harm to ultimate recovery.
We use the information in Form BSEE-0126, Well Potential Test Report, for reservoir, reserves, and conservation
No questions of a sensitive nature are asked. We protect proprietary information according to the Freedom of Information Act (5 U.S.C. 552) and DOI's implementing regulations (43 CFR 2); 30 CFR 250.197,
Agencies must also estimate the non-hour paperwork cost burdens to respondents or recordkeepers resulting from the collection of information. Therefore, if you have other than hour burden costs to generate, maintain, and disclose this information, you should comment and provide your total capital and startup cost components or annual operation, maintenance, and purchase of service components. For further information on this burden, refer to 5 CFR 1320.3(b)(1) and (2), or contact the Bureau representative listed previously in this notice.
We will summarize written responses to this notice and address them in our submission for OMB approval. As a result of your comments, we will make any necessary adjustments to the burden in our submission to OMB.
United States International Trade Commission.
Institution of investigation and scheduling of hearing.
Following receipt on August 5, 2015, of a request from the U.S. Trade Representative (USTR) under section 131 of the Trade Act of 1974 (19 U.S.C. 2151), the U.S. International Trade Commission (Commission) instituted investigation no. 131-041,
September 11, 2015: Deadline for filing requests to appear at the public hearing.
September 15, 2015: Deadline for filing prehearing briefs and statements.
September 25, 2015: Public hearing.
October 2, 2015: Deadline for filing posthearing briefs and statements.
October 2, 2015: Deadline for filing all other written submissions.
November 4, 2015: Transmittal of Commission report to the USTR.
All Commission offices, including the Commission's hearing rooms, are located in the United States International Trade Commission Building, 500 E Street SW., Washington, DC. All written submissions should be addressed to the Secretary, United States International Trade Commission, 500 E Street SW., Washington, DC 20436. The public record for this investigation may be viewed on the Commission's electronic docket (EDIS) at
Project leader Renee Berry (202-205-3498 or
The USTR stated that portions of the Commission's report will be classified as national security information and that the USTR considers the report to be an inter-agency memorandum that will contain pre-decisional advice and be subject to the deliberative process privilege.
Any submissions that contain confidential business information (CBI) must also conform with the requirements of section 201.6 of the
By order of the Commission.
Notice.
The Department of Labor (DOL) is submitting the Employee Benefits Security Administration (EBSA) sponsored information collection request (ICR) titled, “Settlement Agreements Between a Plan and a Party in Interest,” to the Office of Management and Budget (OMB) for review and approval for continued use, without change, in accordance with the Paperwork Reduction Act of 1995 (PRA), 44 U.S.C. 3501
The OMB will consider all written comments that agency receives on or before September 28, 2015.
A copy of this ICR with applicable supporting documentation; including a description of the likely respondents, proposed frequency of response, and estimated total burden may be obtained free of charge from the RegInfo.gov Web site at
Submit comments about this request by mail or courier to the Office of Information and Regulatory Affairs, Attn: OMB Desk Officer for DOL-EBSA, Office of Management and Budget, Room 10235, 725 17th Street NW., Washington, DC 20503; by Fax: 202-395-5806 (this is not a toll-free number); or by email:
Michel Smyth by telephone at 202-693-4129, TTY 202-693-8064, (these are not toll-free numbers) or by email at
44 U.S.C. 3507(a)(1)(D).
This ICR seeks to extend PRA authority for the Settlement Agreements Between a Plan and Party in Interest information collection. Prohibited Transaction Exemption (PTE) 1994-71 exempts from certain Employee Retirement Income Security Act of 1974 (ERISA) and Internal Revenue Code of 1986 (Code) section 4975(c)(2) restrictions a settlement agreement entered into between an employee benefit plan and a party in interest resulting from a DOL investigation the plan. PTE 2003-39 similarly exempts a settlement agreement entered into between a plan and a party in interest in avoidance of litigation from certain ERISA restrictions and certain taxes of the Code. ERISA section 408(a) authorizes this information collection.
This information collection is subject to the PRA. A Federal agency generally cannot conduct or sponsor a collection of information, and the public is generally not required to respond to an information collection, unless it is approved by the OMB under the PRA and displays a currently valid OMB Control Number. In addition, notwithstanding any other provisions of law, no person shall generally be subject to penalty for failing to comply with a collection of information that does not display a valid Control Number.
OMB authorization for an ICR cannot be for more than three (3) years without renewal, and the current approval for this collection is scheduled to expire on August 31, 2015. The DOL seeks to extend PRA authorization for this information collection for three (3) more years, without any change to existing requirements. The DOL notes that existing information collection requirements submitted to the OMB receive a month-to-month extension while they undergo review. For additional substantive information about this ICR, see the related notice published in the
Interested parties are encouraged to send comments to the OMB, Office of Information and Regulatory Affairs at the address shown in the
• 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 methodology 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,
Merit Systems Protection Board.
Notice.
In compliance with the Paperwork Reduction Act (PRA), the U.S. Merit Systems Protection Board (MSPB) is submitting a request for a three-year extension of an Information Collection Request (ICR) to the Office of Management and Budget (OMB) for review and approval. This ICR describes the nature of the information collection and its estimated burden and cost.
Submit written comments on or before September 28, 2015.
Submit your comments concerning this ICR by one of the following methods:
You also may submit comments to MSPB by one of the following methods:
Requests for additional information should be directed to Dr. Dee Ann Batten by phone at (202) 254-4495; by email at
Under PRA (44 U.S.C. 3501-3520), Federal agencies must obtain approval from OMB for each collection of information they conduct or sponsor. The MSPB intends to ask for a three-year renewal of its Generic Clearance Request for Voluntary Customer Surveys, OMB Control No. 3124-0012. On June 19, 2015, MSPB sought public comments on this ICR pursuant to 5 CFR 1320.8(d). See 80 FR 35404. The MSPB did not receive any comments. The MSPB is submitting the ICR to OMB for review and approval according to the procedure prescribed in 5 CFR 1320.12.
Executive Order 12862, “Setting Customer Service Standards,” mandates agencies to identify their customers and survey them to determine the kind and quality of services they want and their level of satisfaction with existing services. The MSPB's customers and stakeholders include persons who file appeals with MSPB for agency actions taken against them (appellants), their representatives, and representatives of the agency which took the action.
These surveys will be used to evaluate how well we are serving our customers in terms of their perceptions of timeliness, fairness, accessibility, and sensitivity to their situation in deciding their appeals. We also have used customer surveys to determine the
National Endowment for the Arts, National Foundation on the Arts and Humanities.
Notice of meetings.
Pursuant to the Federal Advisory Committee Act, as amended, notice is hereby given that one meeting of the Arts Advisory Panel to the National Council on the Arts will be held by teleconference.
All meetings are Eastern time and ending times are approximate:
National Endowment for the Arts, Constitution Center, 400 7th St. SW., Washington, DC 20506.
Further information with reference to these meetings can be obtained from Ms. Kathy Plowitz-Worden, Office of Guidelines & Panel Operations, National Endowment for the Arts, Washington, DC 20506;
The closed portions of meetings are for the purpose of Panel review, discussion, evaluation, and recommendations on financial assistance under the National Foundation on the Arts and the Humanities Act of 1965, as amended, including information given in confidence to the agency. In accordance with the determination of the Chairman of February 15, 2012, these sessions will be closed to the public pursuant to subsection (c)(6) of section 552b of title 5, United States Code.
Nuclear Regulatory Commission.
Regulatory guide; withdrawal.
The U.S. Nuclear Regulatory Commission (NRC) is withdrawing Regulatory Guide (RG) 1.35, “Inservice Inspection of Ungrouted Tendons in Prestressed Concrete Containments.” The regulatory guide is being withdrawn because of changes in NRC regulations, which render the RG obsolete. The withdrawal does not affect the licensing bases of current licensees approved to use RG 1.35.
Please refer to Docket ID NRC-2015-0195 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:
•
•
•
Thomas Herrity, telephone: 301-415-2351, email:
The NRC is withdrawing Regulatory Guide 1.35 because it has been superseded by changes in NRC regulations as set forth in section 50.55a of Title 10 of the
The withdrawal of RG 1.35 does not alter any prior or existing licensing commitments based on its use. Although a regulatory guide is withdrawn, its use in existing licenses is still valid, and changes to the licenses can be accomplished using other regulatory products. Withdrawal of a regulatory guide means that the RG no longer provides useful information or has been superseded by other guidance, technological innovations, congressional actions, or other events. A withdrawn RG should not be used for future NRC licensing activities.
Since RG 1.35 was last revised in 1990, ASME Boiler and Pressure Vessel Code Section XI, Subsection IWL was issued. This subsection addresses the examination and repair/replacement of the reinforced concrete and the post-tensioning systems of concrete containments. The NRC incorporated the requirements of the 1992 Edition of the ASME Boiler and Pressure Vessel Code with the 1992 Addenda of Subsection IWL into its regulations, with specified modifications and limitations, in an amendment to section 50.55a, which was published in the
The guidance provided in RG 1.35 has been incorporated into later revisions of Subsection IWL, or preserved in 10 CFR 50.55a. As a result, RG 1.35 has become redundant and is no longer needed.
For the Nuclear Regulatory Commission.
Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (“Act”),
The Exchange proposes to amend Chapter VI, Section 6, entitled “Acceptance of Quotes and Orders,” of the BX rules to adopt an optional Kill Switch protection.
The text of the proposed rule change is available on the Exchange's Web site at
In its filing with the Commission, the Exchange included statements concerning the purpose of and basis for the proposed rule change and discussed any comments it received on the proposed rule change. The text of these statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant aspects of such statements.
The purpose of the filing is to adopt a new risk protection, a Kill Switch, applicable to all BX Participants. The Kill Switch will allow BX Participants to remove quotes and cancel open orders and prevent new order submission. This feature provides firms with a powerful risk management tool for immediate control of their quote and order activity.
The Exchange proposes to amend Chapter VI, Section 6, entitled “Acceptance of Quotes and Orders,” to add new section (d) to adopt the Kill Switch. The BX Options Kill Switch will be an optional tool that enables Participants to initiate a message(s)
If the Participant selects quotes to be cancelled utilizing the Kill Switch, the BX Participant must send a message to the Exchange to request the removal of all quotes requested for the certain specified Identifier(s).
over the Specialized Quote Feed, which is the market making quoting interface.
If the Participant selects orders to be cancelled utilizing the Kill Switch, the BX Participant must send a message to the Exchange to request the cancellation of all orders requested for the certain specified Identifier(s).
Proposed section (d)(iii) stipulates that after quotes and/or orders are removed/cancelled by the BX Participant utilizing the Kill Switch, the BX Participant will be unable to enter additional quotes and/or orders for the affected Identifier(s) until the BX Participant has made a request to the Exchange and Exchange staff has set a re-entry indicator to enable re-entry.
The Exchange offers many risk mitigation and management tools today including, but not limited to, certain rapid fire risk controls,
The Exchange proposes to implement this rule within ninety (90) days of the implementation date. The Exchange will issue an Options Trader Alert in advance to inform market participants of such date.
The Exchange believes that its proposal is consistent with Section 6(b) of the Act
The individual firm benefits of enhanced risk protections flow downstream to counter-parties both at the Exchange and at other options exchanges, thereby increasing systemic protections as well. Additionally, because the Exchange offers this risk tool to all BX Participants, the Exchange believes it will encourage liquidity generally and remove impediments to and perfect the mechanism of a free and open market and a national market system and protect investors and the public interest.
This optional risk tool as noted above will be offered to all BX Participants. The Exchange further represents that its proposal will operate consistently with the firm quote obligations of a broker-dealer pursuant to Rule 602 of Regulation NMS and that the functionality is not mandatory. Specifically, any interest that is executable against a BX Participant's quotes and orders that are received
A BX Market Makers' obligation to provide continuous two-sided quotes on a daily basis is not diminished by the removal of such quotes and/or orders by utilizing the Kill Switch. BX Market Makers will be required to provide continuous two-sided quotes on a daily basis. BX Market Makers that utilize the Kill Switch will not be relieved of the obligation to provide continuous two-sided quotes on a daily basis, nor will it prohibit the Exchange from taking disciplinary action against a BX Market Maker for failing to meet the continuous quoting obligation each trading day.
With respect to providing information regarding the removal of quotes and/or cancellation of orders as a result of the Kill Switch to the Clearing Participant, each Member that transacts through a Clearing Member on the Exchange executes a Letter of Guarantee wherein the Clearing Member accepts financial responsibility for all Exchange transactions made by the BX Participant on whose behalf the Clearing Member submits the letter of guarantee. The Exchange believes that because Clearing Members guarantee all transactions on behalf of a Participant, and therefore bear the risk associated with those transactions, it is appropriate for Clearing Members to have knowledge of the utilization of the Kill Switch, should the Clearing Member request such notification.
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. The proposal does not impose an undue burden on inter-market competition because all BX Participants may avail themselves of the Kill Switch, which functionality will be optional. The proposed rule change is meant to protect BX Participants in the event the BX Participant is suffering from a systems issue or from the occurrence of unusual or unexpected market activity that would require them to withdraw from the market in order to protect investors. The ability to control risk at either the user or group level will permit the BX Participant to protect itself from inadvertent exposure to excessive risk at the each level. Reducing such risk will enable BX Participants to enter quotes and orders without any fear of inadvertent exposure to excessive risk, which in turn will benefit investors through increased liquidity for the execution of their orders. Such increased liquidity benefits investors because they receive better prices and because it lowers volatility in the options market. For these reasons, the Exchange does not believe this proposal imposes an undue burden on inter-market competition, rather, the proposed rule change will have no impact on competition.
No written comments were either solicited or received.
Within 45 days of the date of publication of this notice in the
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)(7) of the Securities Exchange Act of 1934 (“Act”),
The Exchange proposes to amend CFE rules to clarify the application of CFE requirements relating to reportable positions and ownership and control reports. The scope of this filing is limited solely to the application of the rule amendments to security futures traded on CFE. The only security futures that have been traded on CFE were traded under Chapter 16 of CFE's Rulebook which is applicable to Individual Stock Based and Exchange-Traded Fund Based Volatility Index security futures. CFE does not currently list any security futures for trading. The text of the proposed rule change is attached as Exhibit 4 to the filing but is not attached to the publication of this notice.
In its filing with the Commission, CFE 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. CFE has prepared summaries, set forth in Sections A, B, and C below, of the most significant aspects of such statements.
CFE submitted CFE Rule Certification Submission Number CFE-2015-003 (“CFE-2015-003”) to the CFTC and CFE Rule Filing Number SR-CFE-2015-001 (“SR-CFE-2015-001”)
The purpose of the proposed rule change is to make some clarifying changes with respect to the rule amendments included in the Prior Filings.
First, CFE proposes to further amend Rule 412B to make clear that TPHs and non-TPHs will continue to be required to concurrently report to the Exchange reportable positions relating to Exchange contracts that they are required to report to the CFTC pursuant to CFTC regulations. This is required under current Rule 412B, and the Exchange believes that it continues to be required by Rule 412B as amended by the Prior Filings. However, in order to eliminate any potential ambiguity in this regard, CFE is further amending Rule 412B as amended by the Prior Filings to make this explicit and is changing the title of Rule 412B to specifically reference reportable positions.
Second, CFE proposes to amend CFE Rule 714 (Imposition of Fines for Minor Rule Violations) to make new paragraph (c) of Rule 412B added by the Prior Filings subject to the same summary fine schedule under Rule 714(f)(vii) that already applies with respect to violations of paragraphs (a) and (b) of Rule 412B. Rule 412B(c) is the provision of Rule 412B that requires each TPH that is not a Clearing Member to report to the Exchange the same information regarding the identification and reporting of special accounts relating to CFE contracts that the OCR Rule requires each TPH that is a Clearing Member to report to the CFTC. The summary fine schedule under Rule 714(f)(vii) is a Letter of Caution for a first offense, a $7,500 fine for a second offense, a $15,000 fine for a third
Third, CFE is further revising the reportable volume provision in CFE Rule 1602(n)(ii) that is included in CFE's contract specification rule chapter for Individual Stock Based and Exchange-Traded Fund Based Volatility Index security futures to make clear that this provision is referencing the reportable trading volume in one of those products that triggers the requirement to report a volume threshold account to the CFTC.
The Amendment also includes some minor, non-substantive wording changes, such as to delete a reference in Rule 412B(b) to CFTC Form 102S which is not applicable with respect to CFE products.
The Exchange believes that the proposed rule change is consistent with Section 6(b) of the Act,
• To prevent fraudulent and manipulative acts and practices,
• to promote just and equitable principles of trade,
• to foster cooperation and coordination with persons engaged in facilitating transactions in securities,
• to remove impediments to and perfect the mechanism of a free and open market and a national market system, and in general, to protect investors and the public interest.
The Exchange believes that the proposed rule change will strengthen its ability to carry out its responsibilities as a self-regulatory organization. CFE needs to receive the same information relating to reportable positions in CFE contracts from TPHs and non-TPHs that is required to be reported to the CFTC, as well as the information that TPHs and non-TPHs provide to the CFTC under the new OCR Rule, in order to carry out CFE's market surveillance program. The proposed rule change facilitates CFE's ability to receive this information in a form and manner that will allow its seamless integration into the market surveillance program and systems utilized by CFE and its regulatory services provider by making explicit that TPHs and non-TPHs are required to provide this information to CFE in a form and manner prescribed by the Exchange.
CFE does not believe that the proposed rule change will impose any burden on competition not necessary or appropriate in furtherance of the purposes of the Act, in that the rule change enhances CFE's market surveillance program. The Exchange believes that the proposed rule change is equitable and not unfairly discriminatory because the amendments would apply equally to all TPHs and non-TPHs that are subject to the applicable requirements.
No written comments were solicited or received with respect to the proposed rule change.
The proposed rule change will become effective on or after September 30, 2015, on a date to be announced by the Exchange through the issuance of a circular. At any time within 60 days of the date of effectiveness of the proposed rule change, the Commission, after consultation with the CFTC, may summarily abrogate the proposed rule change and require that the proposed rule change be refiled in accordance with the provisions of Section 19(b)(1) of the Act.
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Securities and Exchange Commission (“Commission”).
Notice of an application under section 6(c) of the Investment Company Act of 1940 (“Act”) for an exemption from section 15(a) of the Act and rule 18f-2 under the Act, as well as from certain disclosure requirements in rule 20a-1 under the Act, Item 19(a)(3) of Form N-1A, Items 22(c)(1)(ii), 22(c)(1)(iii), 22(c)(8) and 22(c)(9) of Schedule 14A under the Securities Exchange Act of 1934, and Sections 6-
Secretary, U.S. Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090. Applicants: Abbey Capital Limited, 1-2 Cavendish Row, Dublin 1, Ireland; and Michael P. Malloy, Esq., Drinker Biddle & Reath LLP, One Logan Square, Ste. 2000, Philadelphia, PA 19103-6996.
Parisa Haghshenas, Senior Counsel, at (202) 551-6723, or Holly Hunter-Ceci, Branch Chief, at (202) 551-6869 (Division of Investment Management, Chief Counsel's Office).
The following is a summary of the application. The complete application may be obtained via the Commission's Web site by searching for the file number, or an applicant using the Company name box, at
1. The Adviser will serve as the investment adviser to each Subadvised Series pursuant to an investment advisory agreement with the Company (the “Investment Advisory Agreement”).
2. Applicants request an exemption to permit the Adviser, subject to Board approval, to hire a Non-Affiliated Sub-Adviser or a Wholly-Owned Sub-Adviser, pursuant to Sub-Advisory Agreements and materially amend Sub-Advisory Agreements with Non-Affiliated Sub-Advisers and Wholly-Owned Sub-Advisers without obtaining the shareholder approval required under section 15(a) of the Act and rule 18f-2 under the Act.
3. Applicants agree that any order granting the requested relief will be subject to the terms and conditions stated in the Application. Such terms and conditions provide for, among other safeguards, appropriate disclosure to Subadvised Series' shareholders and notification about sub-advisory changes and enhanced Board oversight to protect the interests of the Subadvised Series' shareholders.
4. Section 6(c) of the Act provides that the Commission may exempt any person, security, or transaction or any class or classes of persons, securities, or transactions from any provisions of the Act, or any rule thereunder, if such relief is necessary or appropriate in the public interest and consistent with the protection of investors and purposes fairly intended by the policy and provisions of the Act. Applicants believe that the requested relief meets this standard because, as further explained in the Application, the Investment Advisory Agreements will remain subject to shareholder approval, while the role of the Sub-Advisers is substantially equivalent to that of individual portfolio managers, so that requiring shareholder approval of Sub-Advisory Agreements would impose unnecessary delays and expenses on the Subadvised Series. Applicants believe that the requested relief from the Disclosure Requirements meets this standard because it will improve the Adviser's ability to negotiate fees paid to the Sub-Advisers that are more advantageous for the Subadvised Series.
For the Commission, by the Division of Investment Management, under delegated authority.
Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934 (“Act”),
The Exchange proposes to make adjustments to its Options Regulatory Fee (“ORF”) by amending Section IV, Part D of the Pricing Schedule.
While changes to the Pricing Schedule pursuant to this proposal are effective upon filing, the Exchange has designated these changes to be operative September 1, 2015 and February 1, 2016, as noted herein.
The text of the proposed rule change is available on the Exchange's Web site at
In its filing with the Commission, the Exchange included statements concerning the purpose of and basis for the proposed rule change and discussed any comments it received on the proposed rule change. The text of these statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant aspects of such statements.
The purpose of the proposed rule change is to: (1) Decrease the ORF from $0.0045 per to $0.0035 as of September 1, 2015 and increase the ORF from $0.0035 to $0.0040 as of February 1, 2016 to account for additional fine revenue, cost reductions and to balance the Exchange's regulatory revenue against the anticipated costs and potential fines; and (2) remove the requirement that the ORF may only be modified semi-annually.
The ORF is assessed to each member for all options transactions executed or cleared by the member that are cleared at The Options Clearing Corporation (“OCC”) in the Customer range (
The ORF is designed to recover a portion of the costs to the Exchange of the supervision and regulation of its members, including performing routine surveillances, investigations, examinations, financial monitoring, and policy, rulemaking, interpretive, and enforcement activities. The Exchange believes that revenue generated from the ORF, when combined with all of the Exchange's other regulatory fees, will cover a material portion, but not all, of the Exchange's regulatory costs. The Exchange will continue to monitor the amount of revenue collected from the ORF to ensure that it, in combination with its other regulatory fees and fines, do not exceed regulatory costs. If the Exchange determines regulatory revenues exceed regulatory costs, the Exchange will adjust the ORF by submitting a fee change filing to the Commission.
The Exchange is proposing to decrease the ORF from $0.0045 to $0.0035 as of September 1, 2015 and increase the ORF from $0.0035 to $0.0040 as of February 1, 2016 in order to account for regulatory revenue from disciplinary actions taken by the Exchange. The Exchange regularly reviews its ORF to ensure that the ORF, in combination with its other regulatory fees and fines, do not exceed regulatory costs. The Exchange believes that decreasing the ORF by $0.0010 from September 1, 2015 through January 31, 2016 and then adjusting the ORF as of February 1, 2016 to $.0040 (a $0.0005 reduction from the current rates), will permit the Exchange to cover a material portion of its regulatory costs, while not exceeding regulatory costs.
The Exchange previously filed a rule change to Section IV, Part D of the Pricing Schedule to specify the frequency with which the Exchange may change the ORF.
The Exchange is proposing to eliminate the requirement that its ORF may be only increased or decreased semi-annually because the Exchange believes it requires the flexibility to amend its ORF as needed to meet its regulatory requirements and adjust its ORF to account for the regulatory revenue that it receives and the costs that it incurs, as evidenced by the adjustments proposed in this rule change. While the Exchange is eliminating the requirement to adjust only semi-annually, it will continue to submit a rule proposal with the Commission for each modification to the ORF and notify participants via an Options Trader Alert of any anticipated change in the amount of the fee at least thirty (30) calendar days prior to the effective date. The Exchange believes that the prior notification to market participants will provide guidance on the timing of any changes to the ORF and ensure market participants are prepared to configure their systems to properly account for the ORF.
While changes to the Pricing Schedule pursuant to this proposal are effective upon filing, the Exchange has designated these changes to be operative September 1, 2015 and February 1, 2016, as noted herein.
The Exchange believes that the proposed rule change is consistent with the provisions of Section 6 of the Act,
The Exchange believes that lowering the ORF from $0.0045 to $0.0035 as of September 1, 2015 and then increasing the ORF from $0.0035 to $0.0040 as of February 1, 2016 is reasonable because the Exchange's collection of ORF needs to be balanced against the amount of regulatory revenue collected by the Exchange. The Exchange believes that the proposed adjustments noted herein will serve to balance the Exchange's regulatory revenue against the anticipated regulatory costs. It is further reasonable because both price changes discussed herein represent a price reduction compared to the current rate of $0.0045.
The Exchange believes that lowering the ORF from $0.0045 to $0.0035 as of September 1, 2015 and then increasing the ORF from $0.0035 to $0.0040 as of February 1, 2016 is equitable and not unfairly discriminatory because these adjustments would be applicable to all members on all of their transactions that clear as Customer at OCC. In addition, the ORF seeks to recover the costs of supervising and regulating members, including performing routine surveillances, investigations, examinations, financial monitoring, and policy, rulemaking, interpretive, and enforcement activities. The ORF is not charged for member proprietary options transactions because members incur the costs of owning memberships and through their memberships are charged transaction fees, dues and other fees that are not applicable to non-members. Moreover, the Exchange believes the ORF ensures fairness by assessing higher fees to those members that require more Exchange regulatory services based on the amount of Customer options business they conduct. Regulating Customer trading activity is more labor intensive and requires greater expenditure of human and technical resources than regulating non-Customer trading activity. Surveillance, regulation and examination of non-Customer trading activity generally tends to be more automated and less labor intensive. As a result, the costs associated with administering the Customer component of the Exchange's overall regulatory program are anticipated to be higher than the costs associated with administering the non-Customer component of its regulatory program. As such, the Exchange proposes assessing higher fees to those members that will require more Exchange regulatory services based on the amount of Customer options business they conduct.
The Exchange believes that the proposed rule change to remove the limit to amend the ORF only semi-annually, with advance notice, is reasonable because the Exchange will continue to provide market participants with thirty (30) days advance notice of amending its ORF. Also, the Exchange is required to monitor the amount of revenue collected from the ORF to ensure that it, in combination with its other regulatory fees and fines, do not exceed regulatory costs. Therefore, the Exchange believes it is reasonable to remove the semi-annual limit to amend its ORF in order to permit the Exchange to make amendments to its ORF as necessary to comply with the Exchange's obligations.
The Exchange believes that the proposed rule change to remove the limit to amend the ORF only semi-annually, with advance notice, is equitable and not unfairly discriminatory because it will apply in the same manner to all members that are subject to the ORF. Moreover, the Exchange believes that the proposed ORF is a small incremental cost for Customer executions.
Also, all members will continue to receive advance notice of changes to the ORF.
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. The Exchange does not believe that adjusting its ORF creates an undue burden on inter-market or intra-market competition. The Exchange will adjust its ORF for all members on all of their transactions that clear as Customer at OCC. The Exchange is obligated to
The Exchange does not believe that removing the limit to amend the ORF semi-annually, with advance notice, creates an undue burden on competition. The Exchange will continue to provide the same advance notice of changes to the ORF as it does today.
No written comments were either solicited or received.
The foregoing rule change has become effective pursuant to Section 19(b)(3)(A)(ii) of the Act.
Interested persons are invited to submit written data, views and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Pursuant to section 19(b)(1)
The Exchange proposes to reflect a change to the means of achieving the investment objective applicable to the SPDR Blackstone/GSO Senior Loan ETF (the “Fund”) relating to its use of derivative instruments. Shares of the Fund are currently listed and traded on the Exchange under NYSE Arca Equities Rule 8.600 (“Managed Fund Shares”). The text of the proposed rule change is available on the Exchange's Web site at
In its filing with the Commission, the self-regulatory organization included statements concerning the purpose of, and basis for, the proposed rule change and discussed any comments it received on the proposed rule change. The text of those statements may be examined at the places specified in Item IV below. The Exchange has prepared summaries, set forth in sections A, B, and C below, of the most significant parts of such statements.
The Commission has approved listing and trading on the Exchange of shares (“Shares”) of the Fund under NYSE Arca Equities Rule 8.600, which governs the listing and trading of Managed Fund Shares on the Exchange.
Shares of the Fund are currently listed and traded on the Exchange.
On December 6, 2012, the staff of the Commission's Division of Investment Management (“Division”) issued a no-action letter (“No-Action Letter”) relating to the use of derivatives by actively-managed exchange-traded funds (“ETFs”).
The No-Action Letter stated that the Division staff will no longer defer consideration of exemptive requests under the 1940 Act relating to actively-managed ETFs that make use of derivatives provided that they include representations to address some of the concerns expressed in the Commission's March 2010 press release. These representations are: (i) That the ETF's board periodically will review and approve the ETF's use of derivatives and how the ETF's investment adviser assesses and manages risk with respect to the ETF's use of derivatives; and (ii) that the ETF's disclosure of its use of derivatives in its offering documents and periodic reports is consistent with relevant Commission and staff guidance (together, the “No-Action Letter Representations”). The No-Action Letter stated that the Division would not recommend enforcement action to the Commission under sections 2(a)(32), 5(a)(1), 17(a), 22(d), and 22(e) of the 1940 Act, or rule 22c-1 under the 1940 Act if actively-managed ETFs operating in reliance on specified orders (which include the Trust's Exemptive Order
The Prior Release included the following representation: “The Portfolio will not invest in options contracts, futures contracts or swap agreements” (the “Derivatives Representation”). In view of the No-Action Letter, the Exchange is proposing to delete the Derivatives Representation. The Exchange now proposes that, to pursue the Fund's investment objective, the Fund be permitted to invest in options, futures, and swaps (“Derivative Instruments”), as described below.
Going forward, the Portfolio may buy and sell exchange-listed and over-the-counter (“OTC”) swaps based on total return senior loan and credit default indices; futures contracts and options on futures contracts based on senior loan and credit default indices; and exchange-listed and OTC options on senior loan and credit default indices.
The Portfolio will only enter into futures contracts and exchange-traded options on futures contracts that are traded on a national futures exchange that is regulated by the Commodities Futures Trading Commission (“CFTC”) and that is a member of the Intermarket Surveillance Group (“ISG”).
Under normal market conditions, no more than 20% of the value of the Fund's net assets will be invested in Derivative Instruments.
The Prior Release stated that the Portfolio's investments would be consistent with the Portfolio's investment objective and would not be used to enhance leverage. In view of the Exchange's proposal to permit the Fund to use Derivative Instruments, the Portfolio's investments in Derivative Instruments could potentially be used to enhance leverage. However, the Portfolio's investments in Derivative Instruments will be consistent with the Portfolio's investment objective and will not be used to seek to achieve a multiple or inverse multiple of an index.
Investments in Derivative Instruments will be made in accordance with the 1940 Act and consistent with the Fund's investment objective and policies. The Fund will comply with the regulatory requirements of the Commission to maintain assets as “cover,” maintain segregated accounts, and/or make margin payments when it takes positions in Derivative Instruments involving obligations to third parties (
The Fund will include appropriate risk disclosure in its offering documents, including leveraging risk. Leveraging risk is the risk that certain transactions of the Fund, including the Fund's use of Derivative Instruments, may give rise to leverage, causing the Fund to be more volatile than if it had not been leveraged.
Based on the above, the Exchange seeks this modification regarding the Fund's use of Derivative Instruments. The Adviser represents that there is no change to the Fund's investment objective. The Adviser and the Sub-Adviser believe that the ability to invest in Derivative Instruments will provide the Adviser and Sub-Adviser with additional flexibility to meet the Fund's investment objective.
The Fund will continue to comply with all initial and continued listing requirements under NYSE Arca Equities Rule 8.600.
Except for the changes noted herein, all other facts presented and representations made in the Prior Release remain unchanged.
The changes described herein will be effective upon (i) the effectiveness of an amendment to the Trust's Registration Statement disclosing the Fund's intended use of Derivative Instruments and (ii) when this proposed rule change has become operative. The Adviser represents that the Adviser and Sub-Adviser have managed and will continue to manage the Fund in the manner described in the Prior Release, and will not implement the changes described herein until this proposed rule change is operative.
The Adviser believes there will be minimal, if any, impact to the arbitrage mechanism as a result of the use of Derivative Instruments. Market makers and participants should be able to value derivatives as long as the positions are disclosed with relevant information. The Adviser believes that the price at which Shares trade will continue to be disciplined by arbitrage opportunities created by the ability to purchase or redeem Creation Units (as defined in the Prior Release at their net asset value (“NAV”), which should ensure that Shares will not trade at a material discount or premium in relation to their NAV.
The Adviser does not believe there will be any significant impacts to the settlement or operational aspects of the Fund's arbitrage mechanism due to the use of derivatives. Certain derivatives may not be eligible for in-kind transfer, and such derivatives will be substituted with a “cash in lieu” amount when the Fund processes purchases or redemptions of Creation Units (as defined in the Prior Release) in-kind.
As stated in the Prior Release, the NAV per Share for the Fund will be computed by dividing the value of the net assets of the Fund (
U.S. exchange-traded options will be valued at the closing price determined by the applicable exchange. The Fund will generally value exchange-traded futures at the settlement price determined by the applicable exchange. Exchange-traded swaps generally will be valued by pricing services. Non exchange-traded derivatives (
As described in the Prior Release, on each business day, before commencement of trading in Shares in the Core Trading Session on the Exchange, the Fund discloses on its Web site the Disclosed Portfolio as defined in NYSE Arca Equities Rule 8.600(c)(2) that will form the basis for the Fund's calculation of NAV at the end of the business day.
Pricing information for Derivative Instruments traded OTC (
Intra-day and closing price information regarding exchange traded swaps, options (including options on futures) and futures will be available from the exchange on which such instruments are traded. Quotation and last sale information for exchange-traded options cleared via the Options
The Fund's disclosure of derivative positions in the Disclosed Portfolio will include information that market participants can use to value these positions intraday. On a daily basis, the Fund will disclose on the Fund's Web site the following information regarding each portfolio holding, as applicable to the type of holding: Ticker symbol, CUSIP number or other identifier, if any; a description of the holding (including the type of holding, such as type of swap); the identity of the security or other asset or instrument underlying the holding, if any; for options, the option strike price; quantity held (as measured by, for example, par value, notional value or number of shares, contracts or units); maturity date, if any; coupon rate, if any; effective date, if any; market value of the holding; and the percentage weighting of the holding in the Fund's portfolio.
The Exchange represents that trading in the Shares will be subject to the existing trading surveillances, administered by the Financial Industry Regulatory Authority (“FINRA”) on behalf of the Exchange, which are designed to detect violations of Exchange rules and applicable federal securities laws.
The surveillances referred to above generally focus on detecting securities trading outside their normal patterns, which could be indicative of manipulative or other violative activity. When such situations are detected, surveillance analysis follows and investigations are opened, where appropriate, to review the behavior of all relevant parties for all relevant trading violations.
FINRA, on behalf of the Exchange, will communicate as needed regarding trading in the Shares, exchange-traded options, exchange-traded futures and exchange-traded options on futures with other markets and other entities that are members of the ISG, and FINRA, on behalf of the Exchange, may obtain trading information regarding trading in the Shares, exchange-traded options, exchange-traded futures and exchange-traded options on futures from such markets and other entities. In addition, the Exchange may obtain information regarding trading in the Shares, exchange-traded options, exchange-traded futures and exchange-traded options on futures, from markets and other entities that are members of ISG or with which the Exchange has in place a comprehensive surveillance sharing agreement.
All futures contracts, exchange-traded options on futures contracts, and other exchange-traded options contracts in which the Portfolio invests will be traded on markets that are members of ISG.
In addition, the Exchange also has a general policy prohibiting the distribution of material, non-public information by its employees.
The basis under the Act for this proposed rule change is the requirement under section 6(b)(5)
The Exchange believes that the proposed rule change is designed to prevent fraudulent and manipulative acts and practices in that, under normal market conditions, no more than 20% of the value of the Fund's net assets will be invested in Derivative Instruments. The Fund's investments in Derivative Instruments will be consistent with the Fund's investment objective and will not be used to seek to achieve a multiple or inverse multiple of an index. Investments in Derivative Instruments will be made in accordance with the 1940 Act and consistent with the Fund's investment objective and policies. The Fund will comply with the regulatory requirements of the Commission to maintain assets as “cover,” maintain segregated accounts, and/or make margin payments when it takes positions in Derivative Instruments involving obligations to third parties (
The proposed rule change is designed to promote just and equitable principles of trade and to protect investors and the public interest in that the Fund's disclosure of positions in Derivative Instruments in the Disclosed Portfolio will include information that market participants can use to value these positions intraday. On a daily basis, the Fund will disclose on the Fund's Web site specific information regarding each portfolio holding, as applicable to the type of holding. The Fund may use futures contracts and related options for bona fide hedging; attempting to offset changes in the value of securities held or expected to be acquired or be disposed of; attempting to gain exposure to a particular market, index or instrument; or other risk management purposes. In addition, such proposed change will provide the Adviser and Sub-Adviser with additional flexibility in meeting the Fund's investment objective. The Adviser does not believe there will be any significant impacts to the settlement or operational aspects of the Fund's arbitrage mechanism due to the use of derivatives. In addition, the Commission has previously approved the use of derivatives similar to those proposed herein by issues of Managed Fund Shares traded on the Exchange.
The proposed rule change is designed to perfect the mechanism of a free and open market and, in general, to protect investors and the public interest in that it will facilitate the listing and trading of an actively-managed exchange-traded product that will enhance competition among market participants, to the benefit of investors and the marketplace.
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 Exchange believes the proposed rule change will permit the Adviser and Sub-Adviser additional flexibility in achieving the Fund's investment objective, thereby offering investors additional investment options. The proposed rule change will allow the Fund to use Derivative Instruments as a more efficient substitute for taking a position in the underlying asset and/or as part of a strategy designed to reduce exposure to risks (such as interest rate), enhance liquidity or to enhance investment returns. The proposed change, therefore, will provide additional flexibility to the Adviser and Sub-Adviser to seek the Fund's investment objective and will enhance the Fund's ability to compete with other actively managed exchange-traded funds and mutual funds.
No written comments were solicited or received with respect to 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, if consistent with the protection of investors and the public interest, the proposed rule change has become effective pursuant to section 19(b)(3)(A) of the Act
At any time within 60 days of the filing of the proposed rule change, the Commission may temporarily suspend this rule change if it appears to the Commission that such action is necessary or appropriate in the public interest, for the protection of investors, or otherwise in furtherance of the purposes of the Act. If the Commission takes such action, the Commission shall institute proceedings to determine whether the proposed rule should be approved or disapproved.
Interested persons are invited to submit written data, views, and arguments concerning the foregoing, including whether the proposed rule change is consistent with the Act. Comments may be submitted by any of the following methods:
• Use the Commission's Internet comment form (
• Send an email to
• Send paper comments in triplicate to Secretary, Securities and Exchange Commission, 100 F Street NE., Washington, DC 20549-1090.
For the Commission, by the Division of Trading and Markets, pursuant to delegated authority.
Tennessee Valley Authority.
Notice of intent.
The Tennessee Valley Authority (TVA) intends to prepare an Environmental Impact Statement (EIS) to address the closure of coal combustion residual (CCR) impoundments at its coal-fired power plants. CCRs are byproducts produced from the combustion of coal or the control of combustion emissions and include fly ash, bottom ash, boiler slag, and flue gas desulfurization materials. The purpose of this EIS is to facilitate TVA's compliance with the CCR Rule that the U.S. Environmental Protection Agency (EPA) issued on April 17, 2015. This also will provide the public a meaningful opportunity to comment on the issues associated with that effort.
This EIS will programmatically consider the impacts of the two primary closure methods: (1) Closure-in-Place and (2) Closure-by-Removal. It will also consider the site-specific impacts of closing 11 of TVA's impoundments within three years. Public comment is invited concerning the scope of this EIS.
Comments on the scope of the EIS must be received on or before September 30, 2015.
Written comments should be sent to Ashley Farless, Tennessee Valley Authority, 1101 Market St., BR4A, Chattanooga, TN 37402. Comments also may be submitted to
Ashley Farless, 1101 Market Street, BR 4A, Chattanooga, TN 37402, 423.751.2361,
This notice is provided in accordance with the regulations promulgated by the Council on Environmental Quality (40 CFR parts 1500 to 1508) and TVA's procedures implementing the National Environmental Policy Act (
TVA is a federal agency and instrumentality of the United States, established by an act of Congress in 1933. Its broad mission is to foster the social and economic welfare of the people of the Tennessee Valley region and to promote the proper use and conservation of the region's natural resources. One component of this mission is the generation, transmission, and sale of reliable and affordable electric energy.
TVA operates the nation's largest public power system, producing approximately 4 percent of all of the electricity in the nation. TVA provides electricity to most of Tennessee and parts of Virginia, North Carolina, Georgia, Alabama, Mississippi, and Kentucky. Currently, it serves more than 9 million people in this seven-state region. The TVA Act requires the TVA power system to be self supporting and operated on a nonprofit basis and directs TVA to sell electricity at rates as low as are feasible. TVA receives no appropriations.
Most of the electricity is generated on the TVA system from 3 nuclear plants, 10 coal-fired plants, 9 simple-cycle combustion turbine plants, 6 combined-cycle combustion turbine plants, 29 hydroelectric dams, a pumped-storage facility, a wind-turbine facility, a methane-gas cofiring facility, a diesel-fired facility, and several small solar photovoltaic facilities. Only its coal-fired power plants produce CCRs.
Historically, TVA has managed its CCRs in wet impoundments or dry landfills. After a CCR impoundment at its Kingston power plant failed in 2008, TVA committed to converting its CCR impoundments to dry systems. TVA has coal-fired plants and CCR impoundments in Alabama, Kentucky, and Tennessee. Its CCR impoundments or wet CCR management facilities vary in size from less than 10 acres to more than 300 acres. All of TVA's CCR facilities operate under permits issued by the States in which they are located.
EPA's April 2015 CCR Rule establishes national criteria and schedules for the management and closure of CCR facilities. To support this rule, EPA compiled an extensive administrative record, including a number of technical and scientific studies. EPA decided to continue to regulate CCRs as solid waste and determined that compliance with its CCR criteria would ensure that CCR management activities and facilities would not pose a reasonable probability of adverse effects on health or the environment. The rule establishes location restrictions, liner design criteria, structural integrity requirements, operating criteria, groundwater monitoring and corrective action requirements, closure and post-closure care requirements, and recordkeeping, notification, and internet posting requirements.
EPA indicated that current management of CCRs poses risks primarily associated with potential structural failures and groundwater contamination. In its technical analyses, EPA determined that CCR impoundments posed greater risks than CCR landfills because ponded water creates a hydraulic head that can stress impoundment structural integrity and promote groundwater contamination.
EPA's rule establishes two primary closure methods: (1) Closure with CCR in Place and (2) Closure through Removal. Closure-in-Place involves removing standing water from an impoundment and installing a final cover system that minimizes the infiltration of water. Closure-by-Removal involves excavating and relocating the CCRs from an impoundment (or beneficially using them in products or structural fills). EPA observed that most facilities would be closed in place because of the difficulty and cost of Closure-by-Removal. It determined that either closure method would be equally protective if done properly.
TVA has decided to perform a programmatic review of the potential impacts of the two primary closure methods. EPA's technical analyses lend themselves to and support such an approach. Conclusions reached from such a programmatic comparison generally should be applicable to any CCR impoundment on the TVA system regardless of the location. Site specific conditions would affect the potential magnitude of effects, but not the kind of effects. For example, Closure-by-Removal would require excavating the accumulated CCRs and transporting them elsewhere either for beneficial use or disposal in a CCR-compliant or municipal solid waste landfill. In every instance where CCRs are moved off site there would be transportation impacts of some kind and to some degree depending on the transportation distance and method. Identifying, assessing, and contrasting the effects of these two closure methods on a generic basis would allow their merits to be considered by the public, interested stakeholders, and TVA decision makers. In this programmatic review, TVA may be able to identify general criteria for method selection that could be applied to site-specific closure actions when those are assessed.
EPA structured its CCR Rule to encourage regulated entities to accelerate the closure of CCR impoundments because of the significant decrease in risk that results from eliminating the hydraulic head of ponded water. EPA determined that once a CCR impoundment is dewatered and closed, the risks are no greater than those of an inactive CCR landfill that is not subject to additional requirements
Scoping is a process that allows the public to comment on an agency's plans for an EIS. This includes identifying issues that should be studied and those that have little significance. The public's views on the alternatives that should be addressed also can be helpful in preparing an EIS.
Programmatically, TVA proposes to examine two closure alternatives, Closure-in-Place and Closure-by-Removal. The EIS will address different methods of implementing the two closure approaches, including partial removal of CCRs. Various kinds of caps or surface liners could be used for Closure-in-Place and the merits of those approaches, sub-alternatives, will be addressed. Closure-by-Removal could involve moving CCRs off-site by truck, rail, or barge transportation and the potential impacts of these alternative transportation methods would be addressed. At the site-specific level, TVA will examine in more specific detail the implications of closing these eleven impoundments. TVA encourages the public to comment on this.
At either the programmatic or site-specific level, the typical range of resource impacts addressed in EISs would be assessed. This would include surface and groundwater impacts that were a focus of EPA's technical assessments. It also is likely that Closure-in-Place or Closure-by-Removal would involve movements to and from borrow areas to obtain cover material (soil, clay). For Closure-by-Removal, it would be necessary to fill in the depression or hole that is left when CCRs are removed unless it is possible to place the removed CCRs back into the hole after lining the bottom. It also may be possible to beneficially use some of the ash as cover material (structural fill) in lieu of using borrow material to close a dewatered CCR impoundment.
The public is invited to submit comments on the scope of this EIS no later than the date identified in the
Federal Aviation Administration (FAA), U.S. Department of Transportation (DOT).
Third Meeting Notice of RTCA Special Committee 233.
The FAA is issuing this notice to advise the public of the third meeting of the RTCA Special Committee 233.
The meeting will be held September 15th-17th from 8:00 a.m.-4:30 p.m.
The meeting will be held at RTCA Headquarters, 1150 18th Street NW., Suite 910, Washington, DC 20036, Tel: (202) 330-0662.
The RTCA Secretariat, 1150 18th Street NW., Suite 910, Washington, DC, 20036, or by telephone at (202) 833-9339, fax at (202) 833-9434, or Web site at
Pursuant to section 10(a) (2) of the Federal Advisory Committee Act (Pub. L. 92-463, 5 U.S.C., App.), notice is hereby given for a meeting of the RTCA Special Committee 233. The agenda will include the following:
Attendance is open to the interested public but limited to space availability. With the approval of the chairman, members of the public may present oral statements at the meeting. Persons wishing to present statements or obtain information should contact the person listed in the
Federal Transit Administration, DOT.
Notice of Buy America Waiver.
In response to a Buy America waiver request from the Long Island Rail Road (LIRR), a subsidiary of the New York Metropolitan Transportation Authority (MTA), the Federal Transit Administration (FTA) hereby waives its Buy America requirements for the movable point frog component of one track turnout that LIRR needs for Stage 1.1 of its Jamaica Station Capacity Improvements Project, Phase I (JCI-Phase 1 Project). The turnout itself, however, is subject to FTA's Buy America requirements and, accordingly, the turnout must be manufactured in the United States.
This Buy America waiver does not apply to track turnout components for Stages 2.0.1, 2.0.2, 2.0.3, and any other stages of LIRR's JCI-Phase I Project, or for LIRR's State of Good Repair Program, as LIRR has withdrawn such waiver
This waiver is effective immediately.
Richard L. Wong, FTA Attorney-Advisor, at (202) 366-4011 or
The purpose of this notice is to announce that FTA is granting a non-availability Buy America waiver for the movable point frog component (also known and referred to as a “vee point”) on one track turnout that LIRR needs for Stage 1.1 of LIRR's JCI-Phase I Project.
FTA is providing LIRR with Federal funds to support its JCI-Phase I Project, the total cost of which is approximately $301,653,240. With certain exceptions, FTA's Buy America requirements prevent FTA from obligating Federal funds for a project unless “the steel, iron, and manufactured goods used in the project are produced in the United States.” 49 U.S.C. 5323(j)(1) (2012). All “manufactured end products” must be produced in the United States, and FTA considers a manufactured product to be produced in the United States if: (1) All of the manufacturing processes for the product take place in the United States, and (2) all of the components of the product are of U.S. origin. 49 CFR 661.5(d) (2014). FTA considers a component to be of U.S. origin if it is manufactured in the United States, regardless of the origin of its subcomponents. 49 CFR 661.5(d)(2). If, however, FTA determines that “the steel, iron, and goods produced in the United States are not produced in a sufficient and reasonably available amount or are not of a satisfactory quality,” then FTA may issue a non-availability waiver of these requirements. 49 U.S.C. 5323(j)(2)(B); 49 CFR 661.7(c).
Through the JCI-Phase I Project, LIRR will reconfigure its tracks in Jamaica Station, construct a new passenger platform to facilitate LIRR service to Atlantic Terminal, and increase capacity for LIRR train service into the new Grand Central Terminal following completion of the East Side Access Project. Currently, Jamaica Station is one of the busiest stations in LIRR's system, with over 250,000 customers and 500 trains passing through the station each weekday. Phase 1 of the project is divided into Stages 1 and 2.
The scope of work for the project involves the installation of new track turnouts. In June 2013, LIRR issued a solicitation for two turnouts containing rail bound magnesium frogs in connection with Stage 1 of the JCI-Phase I Project. On May 16, 2014, LIRR awarded Contract Number 6121 to Picone Schiavone II, which certified its compliance with FTA's Buy America requirements for the track turnouts. Following the award, LIRR determined that these turnouts would be insufficient to meet LIRR's operational needs. Accordingly, LIRR revised its specifications for the project to include two turnouts with movable point frogs, which is the component type that is the subject of this waiver.
The movable point frogs are essential components of track turnouts, and LIRR indicated that it needs them for the following operational reasons: (1) They are necessary to withstand the frequent and heavy use by passenger and freight trains traveling along LIRR's right of way; (2) they allow trains to travel through the turnouts at higher speeds, ultimately providing more throughput during rush hour; (3) they reduce impact loading to the turnouts; and (4) they provide for less wear and tear, thereby requiring less overall maintenance, extending the useful lives of the turnouts, and resulting in fewer outages and negative impacts on LIRR's operations. Picone Schiavone II advised LIRR that it was unable to certify compliance with FTA's Buy America requirements based upon LIRR's new specifications requiring movable point frogs as components of the track turnouts.
By letter dated September 19, 2014, LIRR requested a non-availability Buy America waiver for four components that LIRR needs for ten track turnouts on Stages 1.1, 2.0.1, 2.0.2, and 2.0.3 of its JCI-Phase I Project. Those four components are the Schwihag roller assemblies, Schwihag plates, ZU1-60 steel switch point rail sections, and the movable point frogs. At the time that LIRR submitted its waiver request, none of these turnout components were manufactured in the United States. The roller assemblies and plates were manufactured in Switzerland, the ZU1-60 steel switch point rail sections were manufactured in Austria, and the movable point frogs were manufactured in Germany.
Based on previous solicitations, LIRR concluded that it was unable to identify a domestic source for these four track turnout components. LIRR also pointed to market research and manufacturer outreach that it had conducted for a prior Buy America waiver request related to the East Side Access Project.
Given LIRR's extensive market research, on December 19, 2014 FTA published a
After the docket closed, by letter dated February 13, 2015, LIRR indicated to FTA that it had become aware of alternate turnout designs that would be compatible with LIRR's infrastructure and available from a domestic manufacturer. LIRR indicated its intention to use this alternate turnout design for its programs and projects, including the JCI-Phase I Project. LIRR specified that the alternate turnout design required modification to meet LIRR's operational requirements and to ensure adequate performance and reliability, considering that over 250,000 customers and 500 trains pass through Jamaica Station each weekday.
Given the alternate design and the potential availability of the turnout components from a domestic manufacturer, LIRR narrowed its waiver request from the ten turnouts needed for Stages 1.1, 2.0.1, 2.0.2, and 2.0.3, to only two turnouts needed for Stage 1.1.
LIRR indicated that it needs the waiver for Stage 1.1 because the procurement of the turnouts in that stage is on a critical path. LIRR calculated that, absent a non-availability waiver for the components of these two turnouts, LIRR's JCI-Phase I Project would be delayed by approximately one year, based on the extended lead times for design modifications, fabrication, and delivery of the alternate turnout design. LIRR withdrew its waiver request with respect to the components of eight turnouts needed for Stages 2.0.1, 2.0.2, and 2.0.3 because the procurement of those turnouts is not on a critical path and LIRR believes that it has enough time to design, fabricate, manufacture, deliver, and install the domestic alternates without causing delays to those stages of the project.
Following LIRR's letter dated February 13, 2015, LIRR engaged in additional efforts to utilize domestic manufacturers for the project. By electronic mail dated June 25, 2015, LIRR further narrowed its waiver request to apply to only one turnout needed for Stage 1.1 of its JCI-Phase I Project. LIRR also withdrew its request for a Buy America waiver with respect to the Schwihag roller assemblies, Schwihag plates, and the ZU1-60 steel switch point rail sections for that turnout. LIRR determined that, based on the project's redesign, LIRR could use domestically manufactured components as alternatives. LIRR limited its waiver request to just the movable point frog needed for a single turnout in Stage 1.1.
Based upon LIRR's good faith efforts to identify domestic manufacturers for the turnout components and redesign the project, LIRR's informed conclusion that there are presently no U.S. manufacturers that are willing and capable of producing the movable point frog critically needed for the project, and the lack of responses to FTA's
This Buy America waiver does not apply to track turnout components for Stages 2.0.1, 2.0.2, 2.0.3, and any other stages of LIRR's JCI-Phase I Project, or for LIRR's State of Good Repair Program, as LIRR has withdrawn such waiver requests. Furthermore, this Buy America waiver does not apply to track turnout components needed for the Northeast Corridor Congestion Relief Project at Harold Interlocking, for which FRA granted a Buy America waiver on May 15, 2015, as FRA funds are being used for that project.
Federal Transit Administration (FTA), U.S. Department of Transportation.
Notice.
The Federal Transit Administration (FTA) annually publishes one or more notices to apportion funds appropriated by law. This notice is the third notice which announces the remaining apportionment for programs funded with fiscal year (FY) 2015 contract authority.
For general information about this notice contact Kimberly Sledge, Director, Office of Transit Programs, at (202) 366-2053. Please contact the appropriate FTA regional office for any specific requests for information or technical assistance. A list of FTA regional offices and contact information is available on the FTA Web site at
The FTA's public transportation assistance program authorization, the Moving Ahead for Progress in the 21st Century Act (MAP-21), expired September 30, 2014. Since that time, Congress has enacted short-term extensions allowing FTA to continue its current programs. The most recent extension, the Highway and Transportation Funding Act of 2015, Public Law 114-41, (July 31, 2015), continues MAP-21 through October 29, 2015. This extension allows FTA to make available contract authority for transit assistance programs through September 30, 2015.
The FTA's full-year appropriations, the Consolidated and Further Continuing Appropriations Act, 2015, Public Law 113-235 (Dec. 16, 2014), hereinafter “Appropriations Act, 2015” was enacted in December 2014, giving FTA appropriated resources for FY 2015 for Administrative Expenses, Capital Investment Grants (CIG), Research and Technical Assistance and Training programs, and Grants to the Washington Metropolitan Area Transportation Authority. The Appropriations Act, 2015 also provides a full fiscal year obligation limitation of $8,595,000,000 of contract authority for FTA programs funded from the Mass Transit Account of the Highway Trust Fund during this fiscal year.
On July 23, 2015, FTA published an apportionments notice that apportioned approximately 10/12ths of the FY 2015 authorized contract authority among potential program recipients based on contract authority that was available from June 1, 2015 through July 31, 2015 (80 FR 141). That notice also provided relevant information about the FY 2015 funding available and end-of-year grant management and application procedures. A copy of that notice and accompanying tables can be found on the FTA Web site at
This document provides notice to stakeholders that FTA is apportioning the full-year FY 2015 authorized contract authority—October 1, 2014 through September 30, 2015—among potential program recipients according to statutory formulas in 49 U.S.C. Chapter 53. This document also allocates most of the remaining CIG funding to projects with existing Full Funding Agreements (FFGA) or projects recommended to receive an FFGA. The FTA has posted tables displaying the funds available to eligible states and urbanized areas on FTA's Web site at
The formula apportionment tables that allocate the full year of FY 2015 appropriated funds can be found at
A. The Transportation Electronic Awards Management (TEAM) system will close on Friday, September 25, 2015. Grants and cooperative agreements must have all applicable assurances and certifications completed so that funds can be awarded by the deadline. Funding that has not been awarded in an application by September 25, 2015 will not be migrated into the new FTA financial system, TrAMS. Instead, these applications will need to be re-created when TrAMS deploys in FY 2016. This applies to new
B. Recipients of open American Recovery and Reinvestment Act (ARRA) grants should be aware that, as a matter of law, all remaining ARRA funds MUST be disbursed from grants by the end of the 5th fiscal year (FY) after funds were required to be obligated. (See 31 U.S.C. 1552.) For FTA ARRA projects, that requirement takes affect at the end of FY 2015. Accordingly, once FTA's ECHO grant payment system closes for disbursement payments on September 25, 2015, all remaining unliquidated funds within FTA ARRA funded grants will no longer be available to the grantee, will be deobligated from the grant, and returned to the U.S. Department of the Treasury. Even if a grantee has incurred costs or disbursed funds prior to the close of ECHO, if the grantee has not actually drawn down the funds by 2:00 p.m. EDT on September 25, 2015 FTA would be unable to reimburse the grantee. Therefore, grantees with open ARRA grants must ensure project activities are completed and all funds are drawdown by 2:00 p.m. EDT on September 25, 2015. For ARRA TIGER I projects, the same requirement will be in effect for the end of FY 2016.
Pipeline and Hazardous Materials Safety Administration (PHMSA), DOT.
Notice of public meeting and request for comments.
PHMSA invites public comments on our intention to request the Office of Management and Budget's (OMB) approval to revise this information collection. On July 30, 2014, (79 FR 44246) PHMSA published a notice and request for comments in the
A public meeting to discuss the revisions to the NPMS will be held on the afternoon of September 10, 2015.
Written comments on this information collection should be submitted by October 26, 2015.
The public meeting will be held at the Crystal City Marriott located at 1999 Jefferson Davis Highway in Arlington, Virginia. Details regarding the meeting can be found at
You may submit written comments identified by Docket No. PHMSA-2014-0092 through one of the following methods:
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Amy Nelson, GIS Manager, Program Development Division, U.S. Department of Transportation, 1200 New Jersey Avenue SE., Washington, DC 20590, by phone at 202-493-0591, or email at
On July 30, 2014, (79 FR 44246) PHMSA published a notice and request for comments in the
PHMSA is publishing this notice to address and respond to the comments received. Please note that technical details pertaining to the new data elements such as domains and reporting requirements for each attribute can be found in the NPMS Operator Standards Manual.
The data being requested is the first substantial update to NPMS submission requirements since the NPMS standards were developed in 1998. The NPMS is PHMSA's only dataset which tracks
Specifically, the new data elements will:
• Aid the industry and all levels of government, from Federal to municipal, in promoting public awareness of hazardous liquid and gas pipelines and in improving emergency responder outreach. Currently, 787 Federal officials, 1,208 state officials and 4,791 county officials have access to the online mapping application. Providing these officials with an improved NPMS containing system-specific information about local pipeline facilities can help ensure emergency response agencies and communities are better prepared and can better execute response operations during incidents.
• Permit more powerful and accurate tabular and geospatial analysis, which will strengthen PHMSA's ability to evaluate existing and proposed regulations as well as operator programs and/or procedures.
• Strengthen the effectiveness of PHMSA's risk rankings and evaluations, which are used as a factor in determining pipeline inspection priority and frequency.
• Allow for more effective assistance to emergency responders by providing them with a more reliable, complete dataset of pipelines and facilities.
• Provide better support to PHMSA's inspectors by providing more accurate pipeline locations and additional pipeline-related geospatial data that can be linked to tabular data in PHMSA's inspection database.
• Better support PHMSA's research and development programs by helping to predict the impact of new technology on regulated pipelines.
PHMSA received wide-ranging comments that provided various points of view on the proposed attributes and the effect the collection of this data would have on the Pipeline Safety program, the pipeline industry, and the general public. After much research and consideration, PHMSA has decided not to move forward with the following attributes at this time. PHMSA reserves the right to reconsider including these attributes in the future.
PHMSA originally proposed that operators submit data on the installation method of pipe segments that cross bodies of water greater than 100 feet in width. Operators would have selected from options such as open cut, trenchless technologies, pipe spans, etc. The Pipeline Safety Trust and COGENT supported including this information as originally proposed. Energy Transfer Partners submitted comments indicating a willingness to provide this information but noted that for many lines this information may not exist. The American Gas Association (AGA), the Texas Pipeline Association (TPA), TransCanada, InterMountain Energy Company, and the American Petroleum Institute commenting jointly with Association of Oil Pipelines (API/AOPL) noted that the installation method does not provide a reliable estimate for the depth of cover. Spectra Energy Partners and Vectren submitted comments suggesting that this attribute would not be useful for risk assessments. Avista commented that they did not possess this information within their Geographic Information Systems (GIS) infrastructure. PHMSA has decided not to move forward with including this attribute in the NPMS at this time.
PHMSA originally proposed to collect the year and type of last direct assessment, as it is used to verify the integrity of the pipeline and is used in pipeline risk calculations. Comments received from the Pipeline Safety Trust supported including this attribute while those from TransCanada, Vectren, Energy Transfer, TPA, and AGA were opposed. PHMSA has determined that the year and type of the last Inline Inspection Instrument (ILI) assessment and last pressure test were most valuable for integrity evaluation. Further, PHMSA determined that the data regarding which lines have been subject to direct assessment can be deduced. As a result, PHMSA has decided not to move forward with this attribute at this time.
PHMSA proposed that operators submit information on the type of leak detection system used. Comments submitted by the Pipeline Safety Trust and COGENT supported including the attribute. The American Petroleum Institute, commenting jointly with Association of Oil Pipelines (API/AOPL), did not oppose including this attribute. However, API/AOPL requested delayed compliance as part of a three-phase implementation and that PHMSA include the option to submit more than one type of leak detection technology. The remaining comments from TransCanada, Spectra Energy Partners, Vectren, Energy Transfer Partners, Energy Transfer, DTE Gas Company, TPA, and AGA were critical of including this attribute. These comments focused primarily on the lack of a perceived safety or risk benefit for knowing what leak detection technologies were in place. InterMountain Gas Company and Avista noted that they did not have this information on a geospatial level within their GIS infrastructure. PHMSA has decided not to move forward with including this attribute in the NPMS at this time.
PHMSA proposed that operators denote whether a pipe segment is part of a PHMSA special permit and report the special permit number. PHMSA received comments from COGENT and Spectra Energy Transfer supporting including this attribute as well as critical comments from API/AOPL, TPA, Energy Transfer, and TransCanada. Those opposed argued that since PHMSA issues special permits, requiring operators to submit this information would be duplicative. At this time PHMSA believes it would be better to collect this information via inspections or the special permitting and reporting process itself rather than in this revision to the NPMS.
PHMSA proposed that operators of offshore gas gathering pipelines make NPMS data submissions. PHMSA received comments from COGENT and Energy Transfer Partners, whom were not opposed to including this attribute to NPMS. COGENT requested all onshore gathering lines be required to submit data to NPMS. TPA submitted comments claiming that this attribute would create a new class of pipelines and is therefore not an appropriate action for an information collection revision. PHMSA has decided not to move forward with including this attribute in the NPMS at this time.
Throughput is used to denote a pipeline's capacity by stating the pipeline's ability to flow a measured amount of product per unit of time. PHMSA received a positive comment from COGENT supporting the inclusion of this attribute in the NPMS. PHMSA received comments from 13 major industry trade associations and operators strongly opposed to collecting this attribute. Those opposed primarily argued that this attribute exceeds PHMSA's regulatory authority, and that the data requested poses a security and commercial risk. AGA, TPA, Avista, Spectra Energy Partners, and InterMountain Gas Company further noted that this information is difficult to measure, collect, and report due to constant fluctuations in market forces and pipeline flow. American Fuel and Petrochemical Manufacturers, TPA, and InterMountain questioned the risk assessment and emergency response value of collecting this information. PHMSA has decided not to proceed with this attribute as proposed, due to potential jurisdictional conflict with the Department of Energy.
PHMSA proposes liquid pipeline operators submit a geospatial point file containing the locations of refineries. PHMSA received a comment from COGENT in support of including this attribute and another comment from Energy Transfer indicating a willingness to provide this information. Critical comments from AFPM, Spectra Energy Partners, API/AOPL, TPA, and AGA strongly opposed the inclusion of this attribute. These groups primarily claimed that these facilities are outside of PHMSA's regulatory jurisdiction and that pipeline operators do not control them. Due to potential jurisdictional issues, PHMSA is not moving forward with this attribute for this revision to the NPMS.
PHMSA proposes gas transmission operators submit a geospatial point file containing the locations of gas process/treatment plants. PHMSA received a comment from COGENT in support of including this attribute and another comment from Energy Transfer indicating a willingness to provide this information. Critical comments from AFPM,1 0474147Spectra Energy Partners, API/AOPL, TPA, and AGA strongly opposed the inclusion of this attribute. These groups claimed these facilities are outside of PHMSA's regulatory jurisdiction and that pipeline operators do not control them. Due to potential jurisdictional issues, PHMSA is not moving forward with this attribute for this revision to the NPMS.
After careful consideration of the comments received, along with the agency's Pipeline Safety goals, PHMSA has decided to move forward with the proposal to collect geospatial data on the following pipeline attributes:
PHMSA originally proposed that for pipeline segments located within Class 3, Class 4, High Consequence Areas (HCA), or “could affect” High Consequence Areas (HCAs), operators submit data to the NPMS with a positional accuracy of five feet. PHMSA further proposed that for all pipeline segments located within Class 1 or Class 2 locations, operators submit data to the NPMS with a positional accuracy of 50 feet.
PHMSA received 24 comments on positional accuracy. COGENT's comments supported the original proposal of five foot positional accuracy. The Pipeline Safety Trust echoed this support, and noted many states already require more stringent accuracy standards though did not cite a specific figure. PHMSA received a number of comments from industry associations and operators which recognized the need for improved positional accuracy, but were highly critical of the five foot positional accuracy standard. Commenters noted that the vast majority of mileage was not mapped to this level of precision, and that some portions of this mileage may
PHMSA proposes that hazardous liquid pipeline operators submit data with a positional accuracy of ± 50 feet. Gas transmission operators are required to submit data at ± 50 feet accuracy for all segments which are in a Class 2, Class 3, or Class 4 area; are within a HCA or have one or more buildings intended for human occupancy; an identified site (See 49 CFR 192.903); a right-of-way for a designated interstate; freeway, expressway, or other principal 4-lane arterial roadway as defined in the Federal Highway Administration's “Highway Functional Classification Concepts” within its potential impact radius. All other gas pipeline segments must be mapped to a positional accuracy of ± 100 feet. PHMSA concedes that ± five feet may be unobtainable for certain locations and is difficult to maintain when GIS data is reprojected as part of its processing, but reiterates its need for a high level of positional accuracy. Any accuracy standard coarser than 100 feet would not achieve the level of detail required to make basic estimates of where a pipeline is located with relation to communities, infrastructure, and landmarks. These risk-based requirements require greater levels of stringency for locations with the highest potential consequences of pipeline incidents, while reducing the data collection burden for remote pipelines. These revisions to the positional accuracy requirements help satisfy the recommendations issued in NTSB recommendations P-15-4, “Increase the positional accuracy of pipeline centerlines and pipeline attribute details relevant to safety in the National Pipeline Mapping System.” Additionally, PHMSA needs to improve its ability to identify pipe segments which cross water. Many recent pipeline accidents, such as the Yellowstone River accident earlier this year, have occurred at or near water crossings. Pipeline right-of-ways frequently run alongside water bodies and PHMSA requires better positional accuracy to determine whether a pipe is running alongside water or under the water body.
PHMSA originally proposed requiring operators to submit data on the nominal diameter of a pipe segment. Knowing the diameter of a pipeline can help emergency responders determine the impact area of a pipeline in the event of a release. This attribute also gives PHMSA the opportunity to gain a broader understanding of the diameters of pipe being operated in any given geographical region, and to further assess potential impacts to public safety and the environment.
PHMSA received eleven comments in support of including mandatory reporting of pipe diameter in the revised information collection. This included industry associations, public interest groups, and individual operators. Most concerns centered on clarification regarding whether PHMSA was requesting nominal or actual diameter. Those commentators included Questar, TransCanada, Spectra, SW Gas, PST, COGENT, INGAA, API, TPA, and AGA. Energy Transfer was critical of the safety benefit of incorporating this attribute, but was willing to provide the information.
PHMSA proposes to move forward with this attribute as originally proposed. This attribute measures the nominal pipe diameter in inches to three decimal places. The primary benefit for incorporating this attribute is that a larger pipe may pose a greater hazard during a rupture. Knowing the location of large lines in relation to populated areas will help PHMSA effectively prioritize inspections and emergency response planning.
PHMSA originally proposed to collect data on the nominal wall thickness of a pipe. PHMSA intends to collect this information as originally proposed. The Pipeline Safety Trust and COGENT supported collecting this information as proposed. API/AOPL submitted comments expressing a willingness to collect this information but requested clarifications of PHMSA's expectation and that this requirement be phased in over time. Energy Transfer requested clarification on whether this attribute would be reported on a predominate basis. AGA commented that an attribute indicating whether a pipeline was operating above 30% SMYS would capture most rupture risk. TPA and Vectren submitted comments arguing that this attribute is not a necessary risk measure if percentage of SMYS is measured. Spectra Energy Partners commented that many interstate gas lines have many changes in wall thickness; therefore, capturing this information on an actual basis would greatly increase segmentation of the data. PHMSA intends to collect this information as originally proposed. For clarification, PHMSA is requesting the nominal wall thickness. This information will not be collected on a predominant basis. PHMSA analysts and inspectors identified this as a fundamental piece of descriptive information for pipeline risk. This information is especially critical for determining the relative risk of corrosion.
PHMSA proposed operators submit commodity details for pipelines if the transported commodity is crude oil, product or natural gas, and subcategories of each. The list of commodity choices is available in the NPMS Operator Standards Manual (Appendix A). Other choices may be added as the need arises.
The Pipeline Safety Trust, COGENT INGAA, AGA, Questar Pipeline Company, Spectra Energy Partners, Energy Transfer Partners, and Southwest Gas supported including this attribute. Energy Transfer requested clarification, and API/AOPL and TransCanada supported a more limited version of this attribute as the commodity in hazardous liquid lines can change day to day.
PHMSA will move forward with this collection with minor modifications from the original proposal. Please see the NPMS Operator Standards Manual for more detailed information on how this information is to be reported. This level of detail is required because of potential differences in leak characteristics, rupture-impacted hazardous areas and a pipeline's internal integrity. Emergency responders will also be able to better respond to pipeline incidents if they know the specific type of commodity being transported.
PHMSA originally proposed that operators submit data on pipe material.
PHMSA originally proposed that operators submit information on the predominant pipe grade of a pipeline segment. The Pipeline Safety Trust supported including this attribute and API did not oppose its collection. AGA, TPA, and an operator believed this attribute was redundant because percentage of SMYS captured the risk from pipe grade. TransCanada and Vectren had concerns about reporting this attribute on a “predominant” basis. Energy Transfer Partners were willing to provide the data but believed the data format noted is insufficient. This information is essential in issues regarding pipe integrity, and is a necessary component in determining the allowable operating pressure of a pipeline. The list of pipe grades is available in the NPMS Operator Standards (Appendix A).
PHMSA proposed operators submit data on the pipe join method. Operators will indicate whether pipes within the segment were welded, coupled, screwed, flanged, used plastic pipe joints, or other.
COGENT and the Pipeline Safety Trust submitted comments supporting including this information. Spectra Energy Partners and Energy Transfer Partners submitted comments opposed to incorporating this attribute on a joint-by-joint basis, though Energy Transfer Partners was receptive to reporting this information on a predominant basis. TPA, TransCanada, and Vectren submitted comments critical of the value of this attribute for risk assessment. InterMountain, MidAmerican, and Avista noted that they did not have this information in their mapping systems, and AGA and API/AOPL noted that it would be burdensome for many operators to collect and record this information. Energy Transfer Partners commented that this information is on the annual reports. PHMSA analysts and inspectors would use this information to identify high-risk joining methods and will be used in PHMSA's risk rankings and evaluations. These models are used to determine pipeline inspection priority and frequency.
PHMSA proposes operators submit information pertaining to the percent at which the pipeline is operating to SMYS. Specifically, operators would submit hoop stress corresponding to the maximum operating pressure (MOP) or maximum allowable operating pressure (MAOP) as a percentage of SMYS. PHMSA uses the established percent SMYS to determine low- and high-stress pipelines, class locations, test requirements, inspection intervals, and other requirements in the pipeline safety regulations.
AGA, API/AOPL, TPA, Vectren, and Southwest Gas raised concerns about securing this information. AGA, TPA, Intermountain, and DTE Gas Company further proposed that this attribute should be calculated based on Maximum Allowable Operating Pressure (MAOP) rather than highest observed operating pressure. AGA and a number of gas operators proposed to allow lines operating below 30 percent SMYS be categorized as “low stress” due to a purported low propensity to rupture. Spectra Energy Partners believed that MAOP was a better measure of pipeline risk and that PHMSA could calculate either from other attributes submitted via NPMS. API further suggested that this should be a “phase 2” action. PHMSA intends to move forward with this attribute as originally proposed. PHMSA uses the percentage of operating SMYS to determine low- and high-stress pipelines, class locations, test requirements, inspection intervals, and other requirements in the pipeline safety regulations. Percentage of SMYS is required for determining and confirming MAOP and Maximum Operating Pressure (MOP). This information also helps PHMSA to determine the regulations applicable to each pipe segment along with the probable toughness of the steel and a segment's likelihood of rupturing.
In order to safeguard this information, this information will only be available to individuals with access to the password protected Pipeline Information Management Mapping Application (PIMMA) site. PHMSA needs to collect both percent SMYS and MAOP because, though technically similar, they encapsulate different aspects of the potential risk to the public.
PHMSA proposed that operators submit the maximum MAOP or MOP for a pipeline segment in pounds per square inch gauge.
PHMSA received comments in support of including this attribute from COGENT, the Pipeline Safety Trust, TPA, Energy Transfer Partners, and Spectra Energy Partners. API, AFPM, AGA, Vectren and Southwest Gas submitted comments expressing security concerns. TPA, AGA, and Vectren suggested that this attribute is duplicative of and inferior to percent SMYS as a risk measure. TransCanada suggested replacing this attribute and others with one that indicates whether or not a line is operating below 30 percent SMYS. PHMSA intends to collect this information as previously proposed. While superficially similar to percent SMYS, MAOP/MOP is not identical and captures different elements of pipeline risk. Specifically, PHMSA inspectors identified it as an important element for incident analysis. MAOP/MOP helps enforce pressure levels between segments which are rated for different pressures. PHMSA engineers further noted that it is useful for determining the potential impact radius. This information will be limited to those with PIMMA access or PHMSA employees.
PHMSA proposed operators submit data on the seam type of each pipe segment. Options include: SM = Seamless, LERW = Low frequency or direct current electric resistance welded, HERW = High frequency electric resistance welded, DSAW = Double submerged arc weld, SAW = Submerged arc weld, EFW = Electric fusion weld, LW = Furnace lap weld, FBW = Furnace butt weld, PLAS = Plastic or OTHER = Other.
The Pipeline Safety Trust, COGENT, Southwest Gas supported including this attribute as proposed. Vectren, Energy Transfer, and DTE Gas Company noted that information may not always be available and PHMSA has not allowed an “unknown” option. AGA and TPA were opposed to collecting this information at this time as it may be part of a pending rulemaking. Spectra Energy Partners further noted that long interstate lines may have many changes in seam type. TransCanada commended that this was not as effective of a risk measure as some other pipeline characteristics.
PHMSA intends to collect this information with the possibility of limiting it to Classes 3, 4, and HCAs. This information is used to determine which type of integrity management inspection assessment should apply, is important for risk analysis due to certain time-dependent risky seam types (LF-ERW), and is used to confirm MAOP.
PHMSA originally proposed that operators submit data on the predominant year of original construction (or installation). The year of construction determines which regulations apply to a pipeline for enforcement purposes. The data requested pertained to the year of construction and not the year the pipe was manufactured. On the annual report, operators report the decade of installation. As a result of this revised collection, operators will be able to submit data on the predominant decade of construction or installation. Predominant is defined as 90 percent or higher of the pipe segment being submitted to the NPMS.
Comments from both public safety advocacy groups and pipeline operators were generally positive. AGA and TPA recommended defining this attribute as the year that the segment was placed in service. Vectren recommended defining this on a segment-by-segment basis rather than on a predominant basis. API suggested this be phase 2 in a 3 phase implementation and to allow operators to submit data by decade for lines installed before 1990. Southwest Gas had security concerns and TransCanada and Spectra Energy Partners submitted comments doubting the significance of year of construction on pipeline safety risk. TransCanada further noted that this information is already collected on annual reports.
Collecting this information geospatially rather than in tabular form in the annual reports allows PHMSA to run better risk-ranking algorithms through pattern analysis and relating pipe attributes to surrounding geographical areas. Identifying and protecting aging infrastructure is a DOT priority and collecting this information allows PHMSA to better understand and plan for age-dependent threats.
Onshore/Offshore: PHMSA proposes operators designate whether a pipe segment is onshore or offshore.
PHMSA received four comments on this attribute which were generally supportive. COGENT supported including this information as proposed. API/AOPL, Spectra Energy Partners, and Energy Transfer Partners were willing to provide this information but requested guidance on defining “offshore pipelines” for the purpose of this information collection. API/AOPL further recommended that this information be password protected under PIMMA.
PHMSA will move forward with this attribute as originally proposed. To aid compliance and standardization, PHMSA will issue guidance in the NPMS Operator Standards Manual on how to determine whether a pipeline is offshore or onshore for the purpose of this information collection. Comparisons between the NPMS (PHMSA-generated) offshore mileage statistics and operator-generated annual report offshore mileage statistics do not match. This collection will allow PHMSA to standardize and compare the statistics for regulatory purposes.
PHMSA originally proposed that operators indicate whether their system is capable of accommodating an ILI tool.
The Pipeline Safety Trust and COGENT strongly supported including this attribute, as did a number of industry entities including TransCanada, Spectra Energy Partners, and Energy Transfer. INGAA and Questar proposed a simplified yes/no version of this attribute. API and TPA were receptive to including this information but questioned the safety benefit. AGA and DTE Gas Company submitted critical comments citing difficulty of compliance given the ongoing technological development in pipeline assessment tools. InterMountain Gas Company and Avista noted that they did not have this information in their GIS infrastructure. Vectren noted their view that the information was not needed for risk ranking and was already on the annual report.
PHMSA intends to collect this information as originally proposed. For the purpose of this information collection, this attribute denotes whether a line is capable of accepting an inline inspection tool with currently available technology. Inline Inspection methods information is useful for tracking progress related to NTSB recommendations P-15-18 and P-15-20 which recommend that all natural gas transmission pipelines be capable of being in-line inspected and that PHMSA “identify all operational complications that limit the use of in-line inspection tools in piggable pipelines” respectively.
Operators of gas transmission pipeline segments will be required to submit information on class location (49 CFR 192.5) at the segment level.
PHMSA received eight comments on this attribute which were generally positive. COGENT, Spectra Energy Partners, Southwest Gas, TPA, and AGA submitted comments supporting including this attribute. TransCanada opposed, stating that PHMSA can collect this information at audits and inspections. Avista indicated that they did not have this information within their GIS infrastructure. Spectra Energy Partners and Energy Transfer submitted comments requesting greater clarity and guidance on the definition of segments, as well as expectations for accuracy for the purpose of this collection.
PHMSA intends to collect this information as originally proposed. Operators may consult the NPMS Operator Standards Manual for help in defining segments. This information is a critical measure of population risk, and is necessary to ensure that integrity management rules are properly applied to high-risk areas. Survey requirements vary based on class location, and this data is valuable for prioritizing, planning, and conducting inspections.
PHMSA proposed gas transmission operators identify pipe segments which “could affect” HCAs as defined by 49 CFR 192.903.
AGA, INGAA, TPA, TransCanada, Energy Transfer, Questar Pipeline Company, and COGENT supported collecting data regarding Gas HCAs. AGA, Vectren, and Intermountain requested clarification on how “could affect” HCAs impact gas operators.
PHMSA intends to move forward with the HCA attributes as originally proposed. This information will help emergency responders identify areas with greater potential for significant damage. Additionally, these attributes identify areas subject to integrity management procedures. PHMSA has explicit statutory authority to map high-consequence areas under 49 U.S.C. 60132(d). Gas operators are only expected to submit information on whether that segment lies within an HCA as defined in 49 CFR 192.903.
PHMSA proposed hazardous liquid and gas transmission operators identify pipe segments which could affect HCAs as defined by 49 CFR 195.450. Pipe segments can be classified as affecting a populated area, an ecologically sensitive
TPA and COGENT supported including this information as proposed. API/AOPL, the American Fuel and Petrochemical Manufacturers, and TransCanada had security concerns with including this data element.
PHMSA intends to move forward with the “could affect HCA” attribute as originally proposed. This information will help emergency response planners identify areas with greater potential for significant damage. Additionally it identifies areas subject to integrity management procedures. PHMSA has explicit statutory authority to map high-consequence areas under 49 U.S.C. 60132(d), and NTSB recommendation P-15-5 states that PHMSA should “revise the submission requirement to include HCA identification as an attribute data element to the National Pipeline Mapping System.” This information will be secured with the PIMMA system to mitigate potential security risks.
PHMSA proposes operators submit data detailing the year of a pipeline's last corrosion, dent, crack or “other” ILI assessment. The Pipeline Safety Trust, COGENT, and API/AOPL supported including this attribute, though the latter suggested protecting this information with PIMMA and delaying compliance to Phase Two of their three-phase plan. INGAA, AGA, Spectra and Vectren questioned the safety value of including this attribute. Avista noted that they did not have this information in their GIS infrastructure.
PHMSA intends to move forward with this attribute as originally proposed. This information is used to verify integrity of the pipeline. It is also a key metric in PHMSA's pipeline risk calculations, which are used to determine the priority and frequency of inspections. Inspectors noted that this is important for inspection planning, as a line which has been recently assessed has a statistically lower risk than one that has not recently been assessed. This information will be protected by being placed in PIMMA.
PHMSA proposed operators indicate whether a pipe is effectively coated, and if so the type of coating.
COGENT, Pipeline Safety Trust, TPA, TransCanada and Southwest Gas Company supported including this attribute. AGA, INGAA, API/AOPL, Questar Pipeline Company, and Spectra Energy Partners petitioned for a greatly simplified binary yes/no version of this attribute, possibly reported on a predominant basis. Intermountain and Avista indicated that they did not collect this information in their GIS infrastructure.
PHMSA intends to move forward with this attribute as proposed. The presence and type of coating on a pipeline has a significant impact on corrosion, which remains a major source of risk to both gas transmission and hazardous liquid pipelines.
See previous section. The choices for type of coating (from the NPMS Operator Standards Manual) are: coal tar enamel, fusion bonded epoxy, asphalt, cold applied tape, polyolefin, extruded polyethylene, field-applied epoxy, paint, composite, other, and no coating.
PHMSA proposed operators submit the Facility Response Plan control number and sequence number for applicable liquid pipeline segments.
COGENT, API/AOPL, Spectra Energy Partners, and Energy Transfer Partners were not opposed to collecting this information; API requested this information be protected by PIMMA. TransCanada viewed it as a potential security risk, and supported only including the plan number. AGA and TPA opposed this data element, suggesting that it is not needed for risk prioritization and is therefore not required.
PHMSA intends to move forward with this attribute as originally proposed. Access to the relevant facility response plan number through NPMS would be beneficial to first responders in an emergency situation, especially in areas with multiple pipeline facilities. Furthermore, this would greatly reduce the workload of regional offices and even operators tasked with ensuring compliance with response plan regulations. Since operators are required to have this information, PHMSA believes it should be minimally burdensome to submit it.
PHMSA proposed to collect data on a pipeline's original and most recent hydrostatic test years and pressures. Note that the original pressure test data will be collected in Phase 3 (see section V) and the last pressure test data will be collected in Phase 1. This is to allow operators sufficient time to research the year of the original pressure test. The NPMS Operator Standards Manual also contains a designation if the operator has researched, but not found, the year of the original pressure test.
The Pipeline Safety Trust, COGENT and Energy Transfer Partners supported including this attribute. API/AOPL, TPA, and AGA questioned the value of this attribute, especially the original pressure test, noting that it will greatly increase segmentation of the dataset. API further suggested dropping the original pressure test information. TransCanada, Spectra Energy Partners, and Vectren were all opposed to collecting this attribute. Avista noted that they did not have this information in their GIS infrastructure.
PHMSA intends to move forward with this attribute as originally proposed with slight modifications. PHMSA will allow the more flexible “pressure test” language in recognition of some alternative testing methodologies available to liquid operators. This information is critical for risk assessment. The time elapsed from the last hydrostatic test increases risk of failure.
PHMSA proposed that all gas transmission and hazardous liquid pipelines abandoned after the effective date of this information collection be mandatory submissions to the NPMS. Abandoned lines are not currently required to be submitted to the NPMS. Operators would only need to submit this data in the calendar year after the abandonment occurs. API/AOPL, Energy Transfer Partners, and Dan Ferguson on behalf of Enbridge supported the inclusion of this attribute for newly abandoned lines only. The Pipeline Safety Trust noted that the definition of “abandoned” should match the definition in the Pipeline Safety Regulations (49 CFR parts 192.3 and 195.2) to mean permanently abandoned and emptied lines. COGENT supported the inclusion of this attribute but recommended applying the requirement retroactively to all abandoned pipelines. TPA, DTE Gas, and TransCanada submitted comments questioning the need for this information for risk assessment or integrity management calculation. AGA had concerns that including this attribute would encourage excavators to use NPMS instead of one call in areas where abandoned lines are expected, noting that there is a potential threat to telecommunications infrastructure that uses abandoned gas lines as cable conduits.
PHMSA intends to move forward with this attribute as originally proposed. This information is important for
PHMSA proposes operators submit a geospatial point file containing the locations of pump (for liquid operators) and compressor (for gas transmission operators) stations. COGENT, Spectra Energy Partners, and the Texas Pipeline Association did not oppose this information collection. API/AOPL, TransCanada, and the American Fuel and Petrochemical Manufacturers opposed this data collection due to security concerns. PHMSA intends to move forward with this attribute as originally proposed. Pump and compressor stations are vulnerable areas, and emergency responders need to know their locations for adequate emergency planning. Proximity to a compressor station has also been known to influence the level of stress on nearby segments, making this information valuable for prioritizing inspection resources. Additionally, the stations are often referenced as inspection boundaries for PHMSA's inspectors. Regarding security concerns, this information will be password protected under PIMMA, and PHMSA notes that this information is already available in commercial datasets.
PHMSA proposes operators submit a geospatial point file containing the locations of mainline block valves, the type of valves and the type of valve operators. PHMSA received comments from Spectra Energy Partners and Energy Transfer Partners, who were unopposed to the inclusion of this attribute in NPMS. TPA conceded that valve location could be useful for PHMSA risk evaluation, but that the valve type component of the attribute had no safety benefit. AGA, TPA, Energy Transfer Partners, DTE Gas Company, Vectren, and TransCanada noted that this information is not valuable to emergency responders as they are not permitted to operate block valves. Comments from API/AOPL and Southwest Gas emphasized security concerns. PHMSA will collect mainline block valve locations and associated attributes as described in the NPMS Operator Standards Manual. Valve location can assist emergency responders when working with pipeline operators during an emergency, and it is useful to PHMSA inspectors and partners to identify vulnerable points along a pipeline.
PHMSA proposes operators submit a geospatial polygon file containing the locations of and type of gas storage fields used in interstate gas transmission systems. PHMSA received comments from COGENT and Energy Transfer Partners expressing support for including this attribute. API/AOPL, AGA, TPA, AFPM, DTE Gas Company, and Spectra Energy Partners submitted comments strongly opposed to this proposal. The commenters opposed to including this attribute believe it exceeds PHMSA's jurisdiction and poses a security risk. PHMSA notes that the agency has legal jurisdiction over the transportation of gas which includes “storage of gas in or affecting interstate or foreign commerce”, by the definition of transportation of gas in 49 CFR 192.3. PHMSA further notes that this information would be available only to individuals cleared for access to the PIMMA password protected mapping site. This information would help state and local emergency response planners prepare for incidents involving these facilities. More details on how to submit this data are available in the NPMS Operator Standards Manual.
PHMSA proposed to require the submission of breakout tank data. This is currently an optional submission; this revision would make it mandatory. PHMSA received positive comments from COGENT, API/AOPL, Texas Pipeline Association, and Spectra Energy Partners. API requested security safeguards, and Spectra wanted clarification if it was a point file for each tank or the boundary of a tank farm.
PHMSA intends to proceed with this attribute as originally proposed. As detailed in the NPMS Operator Standards Manual, this information will be stored as a point file for each tank. This helps inspectors locate individual tanks as a tank farm may contain both breakout tanks and other tanks.
PHMSA proposed to collect additional data attributes for liquefied natural gas (LNG) plants used in or affecting interstate commerce. These new attributes include type of plant, capacity, impoundments, exclusion zones and year constructed. COGENT and Spectra Energy Partners submitted comments supporting including this attribute. TPA supported making submitting LNG plant information mandatory but had security concerns with the new descriptive attributes included with this revision. The American Gas Association claimed that existing comprehensive risk analyses performed by the Department of Homeland Security means that PHMSA does not need to include this in its risk analysis on pipelines.
PHMSA intends to proceed with this information as originally proposed. Detailed LNG attributes will be protected by access to PIMMA and only available to PHMSA, state pipeline safety officials, and emergency responders. Geospatial information on the location and characteristics of LNG plants helps PHMSA and emergency responders better understand potential safety risks on a national and local level respectively.
INGAA, API/AOPL, AGA, and GPA submitted comments indicating that some of the proposed attributes appear to be duplicative of information that PHMSA already collects, especially from the annual reports.
A number of operators commented highlighting the expected burden of the proposed revisions to the information collection. Comments submitted by INGAA, API TPA, Ameren, and MidAmerican claimed that PHMSA greatly underestimated the expected burden of this revision. AGA, Ameren Illinois, Laclede Gas Co. and TransCanada noted that a high regulatory burden could divert resources from other safety initiatives such as integrity management and infrastructure replacement activities. Intermountain, Avista, Ameren Missouri, Ameren Illinois, Southwest Gas, AGA, and INGAA noted that many of the proposed changes were beyond the capability of their existing GIS, and would require resources to upgrade systems and hire individuals to convert non-GIS or paper records to an appropriate format.
INGAA, AGA, API/AOPL, and CenterPoint Energy submitted comments suggesting that certain aspects of the proposal exceed what is considered acceptable for an information collection regulated under
PHMSA understands that the new data elements have varying degrees of sensitivity, and that some of the new elements are highly sensitive. PHMSA has discussed the appropriate security categorization for the new data elements with the Transportation Security Administration (TSA). The following new data elements are proposed to be classified as SSI (Sensitive Security Information). These elements would be kept in an SSI-compliant environment at PHMSA. They would be released to no other parties except for government agencies who can verify they maintain an SSI-compliant environment.
The following elements are proposed to be restricted to PIMMA, the mapping application on
The following elements are proposed to be displayed on the NPMS Public Viewer, which can be accessed by the general public.
The Interstate Natural Gas Association of America submitted comments which included an alternative plan for revisions to the NPMS. INGAA proposed to collect only pipe material, nominal diameter, HCA, pipe coating (yes/no), cathodic protection (yes/no), ILI capability (yes/no), and commodity type. INGAA further proposed an alternative positional accuracy requirement of 50 feet for 70 percent of mileage and 100 feet for the remaining 30 percent. PHMSA has addressed the positional accuracy standard in the previous section. PHMSA further finds that the set of attributes proposed by INGAA is inadequate to meet the agency's risk assessment and emergency planning goals.
API/AOPL, INGAA, DTE Gas Company, the Pipeline Safety Trust has serious concerns about the use of the word “predominant.” Other commenters made attribute specific comments to a similar effect. These criticisms centered on how the usage of predominant attributes is poorly defined, difficult to verify compliance with, and risks improper categorization of pipeline risk. For these reasons PHMSA has largely eliminated the option to submit data on a predominant basis.
Spectra Energy Partners requested general guidance on the definition of a segment. Other commenters had attribute-specific comments to a similar effect. This information is defined in more detail in the NPMS Operator Standards Manual.
PHMSA has heard operators' and industry's concerns regarding the amount of time needed to compile, research, and/or prepare the data required for this information collection. PHMSA will collect the new data elements in three phases. Phase 1 data will be collected the first submission year after the effective date, Phase 2 data will be collected the second submission year after the effective date, and Phase 3 data will be collected the third submission year after the effective date. The data elements in each phase are listed below.
The following information is provided for this information collection: (1) Title of the information collection, (2) OMB control number, (3) Current expiration date, (4) Type of request, (5) Abstract of the information collection activity, (6) Description of affected public, (7) Frequency of collection, and (8) Estimate of total annual reporting and recordkeeping burden. PHMSA requests comments on the following information collection:
Number of Respondents: 1,211.
Number of Responses: 1,211.
The agency will summarize and/or include your comments in the request for OMB's clearance of this information collection.
The Paperwork Reduction Act of 1995; 44 U.S.C. chapter 35, as amended; and 49 CFR 1:48.
Alcohol and Tobacco Tax and Trade Bureau (TTB); Treasury.
Notice and request for comments.
As part of our continuing effort to reduce paperwork and respondent burden, and as required by the Paperwork Reduction Act of 1995, we invite comments on the proposed or continuing information collections listed below in this notice.
We must receive your written comments on or before October 26, 2015.
As described below, you may send comments on the information collections listed in this document using the “Regulations.gov” online comment form for this document, or you may send written comments via U.S. mail or hand delivery. TTB no longer accepts public comments via email or fax.
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Please submit separate comments for each specific information collection listed in this document. You must reference the information collection's title, form or recordkeeping requirement number, and OMB number (if any) in your comment.
You may view copies of this document, the information collections listed in it and any associated instructions, and all comments received in response to this document within Docket No. TTB-2015-0001 at
Michael Hoover, Alcohol and Tobacco Tax and Trade Bureau, 1310 G Street, NW., Box 12, Washington, DC 20005; telephone 202-453-1039, ext. 135; or email
The Department of the Treasury and its Alcohol and Tobacco Tax and Trade Bureau (TTB), as part of their continuing effort to reduce paperwork and respondent burden, invite the general public and other Federal agencies to comment on the proposed or continuing information collections listed below in this notice, as required by the Paperwork Reduction Act of 1995 (44 U.S.C. 3501
Comments submitted in response to this notice will be included or summarized in our request for Office of Management and Budget (OMB) approval of the relevant information collection. All comments are part of the public record and subject to disclosure. Please do not include any confidential or inappropriate material in your comments.
We invite comments on: (a) Whether this information collection is necessary for the proper performance of the agency's functions, including whether the information has practical utility; (b) the accuracy of the agency's estimate of the information collection's burden; (c) ways to enhance the quality, utility, and clarity of the information collected; (d) ways to minimize the information collection's burden on respondents, including through the use of automated collection techniques or other forms of information technology; and (e) estimates of capital or start-up costs and costs of operation, maintenance, and purchase of services to provide the requested information.
Currently, we are seeking comments on the following forms, recordkeeping requirements, or questionnaires:
Internal Revenue Service (IRS), Treasury.
Notice and request for comments.
The Department of the Treasury, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to take this opportunity to comment on proposed and/or continuing information collections, as required by the Paperwork Reduction Act of 1995, Public Law 104-13(44 U.S.C. 3506(c)(2)(A)). Currently, the IRS is soliciting comments concerning Notice 2006-25, Qualifying Gasification Project Program.
Written comments should be received on or before October 26, 2015 to be assured of consideration.
Direct all written comments to Christie A. Preston, Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224.
Requests for additional information or copies of the notice should be directed to Martha R. Brinson, Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224, or through the Internet, at
The following paragraph applies to all of the collections of information covered by this notice:
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless the collection of information displays a valid OMB control number. Books or records relating to a collection of information must be retained as long as their contents may become material in the administration of any internal revenue law. Generally, tax returns and tax return information are confidential, as required by 26 U.S.C. 6103.
Internal Revenue Service (IRS), Treasury.
Notice and request for comments.
The Department of the Treasury, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to take this opportunity to comment on proposed and/or continuing information collections, as required by the Paperwork Reduction Act of 1995, Public Law 104-13 (44 U.S.C. 3506(c)(2)(A)). Currently, the IRS is soliciting comments concerning Form 1099-CAP, Changes in Corporate Control and Capital Structure.
Written comments should be received on or before October 26, 2015 to be assured of consideration.
Direct all written comments to Christie Preston, Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224.
Requests for additional information or copies of the form and instructions should be directed to R. Joseph Durbala, at (202) 317-5746, or at Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224, or through the Internet, at
The following paragraph applies to all of the collections of information covered by this notice:
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless the collection of information displays a valid OMB control number. Books or records relating to a collection of information must be retained as long as their contents may become material in the administration of any internal revenue law. Generally, tax returns and tax return information are confidential, as required by 26 U.S.C. 6103.
Request for Comments: Comments submitted in response to this notice will be summarized and/or included in the request for OMB approval. All comments will become a matter of public record. Comments are invited on: (a) Whether the collection of information is necessary for the proper performance of the functions of the agency, including whether the information shall have practical utility; (b) the accuracy of the agency's estimate of the burden of the collection of information; (c) ways to enhance the quality, utility, and clarity of the information to be collected; (d) ways to minimize the burden of the collection of information on respondents, including through the use of automated collection techniques or other forms of information technology; and (e) estimates of capital or start-up costs and costs of operation, maintenance, and purchase of services to provide information.
Internal Revenue Service (IRS), Treasury.
Notice and request for comments.
The Department of the Treasury, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to take this opportunity to comment on proposed and/or continuing information collections, as required by the Paperwork Reduction Act of 1995, Public Law 104-13 (44 U.S.C. 3506(c)(2)(A)). Currently, the IRS is soliciting comments concerning Revenue Procedure 97-27, Changes in Methods of Accounting.
Written comments should be received on or before October 26, 2015 to be assured of consideration.
Direct all written comments to Christie A. Preston, Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224.
Requests for additional information or copies this revenue procedure should be directed to Martha R. Brinson, Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224, or through the Internet at
The following paragraph applies to all of the collections of information covered by this notice:
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless the collection of information displays a valid OMB control number. Books or records relating to a collection of information must be retained as long as their contents may become material in the administration of any internal
Internal Revenue Service (IRS), Treasury.
Notice and request for comments.
The Department of the Treasury, as part of its continuing effort to reduce paperwork and respondent burden, invites the general public and other Federal agencies to take this opportunity to comment on proposed and/or continuing information collections, as required by the Paperwork Reduction Act of 1995, Public Law 104-13 (44 U.S.C. 3506(c)(2)(A)). Currently, the IRS is soliciting comments concerning Form 8569, Geographic Availability Statement.
Written comments should be received on or before October 26, 2015 to be assured of consideration.
Direct all written comments to Christie Preston, Internal Revenue Service, Room 6129, 1111 Constitution Avenue NW., Washington, DC 20224.
Requests for additional information or copies of the form and instructions should be directed to Allan Hopkins at Internal Revenue Service, room 6129, 1111 Constitution Avenue NW., Washington, DC 20224, or through the internet at
The following paragraph applies to all of the collections of information covered by this notice:
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless the collection of information displays a valid OMB control number. Books or records relating to a collection of information must be retained as long as their contents may become material in the administration of any internal revenue law. Generally, tax returns and tax return information are confidential, as required by 26 U.S.C. 6103.
Department of Veterans Affairs.
Notice of Computer Matching Program.
Notice is hereby given that the Department of Veterans Affairs (VA) intends to conduct a recurring computer matching program. This will match personnel records of the Department of Defense (DoD) with VA records of benefit recipients under the Montgomery GI Bill—Active Duty, Montgomery GI Bill—Selected Reserve, Post-9/11 GI Bill, and Reserve Educational Assistance Program.
The goal of these matches is to identify the eligibility status of veterans, servicemembers, and reservists who have applied for or who are receiving education benefit payments under the Montgomery GI Bill—Active Duty, Montgomery GI Bill—Selected Reserve, Post-9/11 GI Bill, and Reserve Educational Assistance Program. The purpose of the match is to enable VA to verify that individuals meet the conditions of military service and eligibility criteria for payment of benefits determined by VA under the Montgomery GI Bill—Active Duty, Montgomery GI Bill—Selected Reserve, Post-9/11 GI Bill, and Reserve Educational Assistance Program.
The authority to conduct this match is found in 38 U.S.C. 3684A(a)(1). The records covered include eligibility records extracted from DoD personnel files and benefit records that VA establishes for all individuals who have applied for and/or are receiving, or have received education benefit payments under the Montgomery GI Bill—Active Duty, Montgomery GI Bill—Selected Reserve, Post-9/11 GI Bill, and Reserve Educational Assistance Program. These benefit records are contained in a VA system of records identified as 58VA21/22/28 entitled: Compensation, Pension, Education, and Vocational Rehabilitation and Employment Records—VA, first published in the
Written comments may be submitted through
Eric Patterson, Strategy and Legislative Development Team Leader, Education Service (225B), Veterans Benefits Administration, Department of Veterans Affairs, 810 Vermont Avenue NW., Washington, DC 20420, (202) 461-9830.
This information is required by paragraph 6c of the “Guidelines on the Conduct of Matching Programs” issued by OMB (54 FR 25818), as amended by OMB Circular A-130, 65 FR 77677 (2000). A copy of the notice has been provided to both Houses of Congress and OMB. The matching program is subject to their review.
Environmental Protection Agency.
Proposed rule.
The Environmental Protection Agency (EPA) is proposing a new subpart that updates the Emission Guidelines and Compliance Times for Municipal Solid Waste Landfills (Emission Guidelines). The EPA determined that it was appropriate to review the landfills Emission Guidelines based on changes in the landfills industry since the Emission Guidelines were promulgated in 1996. The EPA's review of the Emission Guidelines for municipal solid waste (MSW) landfills applies to landfills that accepted waste after November 8, 1987, and commenced construction, reconstruction, or modification on or before July 17, 2014. Based on its initial review, the EPA has determined that it is appropriate to propose revisions to the Emission Guidelines that reflect changes to the population of landfills and the results of an analysis of the timing and methods for reducing emissions. This action proposes to achieve additional reductions of landfill gas (LFG) and its components, including methane, by lowering the emissions threshold at which a landfill must install controls. This action also incorporates new data and information received in response to an advanced notice of proposed rulemaking and addresses other regulatory issues including surface emissions monitoring, wellhead monitoring, and the definition of landfill gas treatment system.
In addition to considering information received in response to this proposed rule in evaluating potential changes to the Emission Guidelines, the EPA intends to consider the information in evaluating whether changes to the requirements for new sources beyond those in the July 17, 2014, proposed rule for new sources are warranted.
The proposed revisions to the Emission Guidelines, once implemented through revised state plans or a revised federal plan, would reduce emissions of LFG, which contains both nonmethane organic compounds and methane. Landfills are a significant source of methane which is a potent greenhouse gas (GHG) pollutant. These avoided emissions will improve air quality and reduce public health and welfare effects associated with exposure to landfill gas emissions.
Submit your comments, identified by Docket ID No. EPA-HQ-OAR-2014-0451, to the Federal eRulemaking Portal:
Please see section II.D of the
For information concerning this proposal, contact Ms. Hillary Ward, Fuels and Incineration Group, Sector Policies and Programs Division, Office of Air Quality Planning and Standards (E143-05), Environmental Protection Agency, Research Triangle Park, NC 27711; telephone number: (919) 541-3154; fax number: (919) 541-0246; email address:
This action proposes changes to the MSW landfills Emission Guidelines resulting from the EPA's review of the Emission Guidelines under Clean Air Act (CAA) section 111. The EPA's review identified a number of advances in technology and operating practices and the proposed changes are based on our evaluation of those advances and our understanding of LFG emissions. The resulting changes to the Emission Guidelines, if adopted, will achieve additional reductions in emissions of landfill gas and its components, including methane. This proposed rule is consistent with the President's 2013 Climate Action Plan,
The EPA reviewed the Emission Guidelines to determine the potential for achieving additional reductions in emissions of LFG. Such reductions would reduce air pollution and the resulting harm to public health and welfare. Significant changes have occurred in the landfill industry over time, including changes to the size and number of existing landfills, industry practices, and gas control methods and technologies. Based on the EPA's initial review, we are proposing changes to the Emission Guidelines. The proposed changes, if adopted, will achieve additional emission reductions of LFG and its components (including methane), provide more effective options for demonstrating compliance, and provide clarification of implementation issues raised during the amendments proposed in 2002 and 2006.
The EPA is not statutorily obligated to conduct a review of the Emission Guidelines, but has the discretion to do so when circumstances indicate that it is appropriate. The EPA has determined that it is appropriate to review and propose changes to the Emission Guidelines at this time based on changes in the landfill industry and changes in the size, ownership, and age of landfills since the Emission Guidelines were promulgated in 1996. The EPA compiled new information on landfills through data collection efforts for a statutorily mandated review of the existing new source performance standards (NSPS) (40 CFR part 60, subpart WWW), public comments received on the NSPS proposal (79 FR 41796, July 17, 2014), and public comments received on the Advanced Notice of Proposed Rulemaking (ANPRM) (79 FR 41772, July 17, 2014) for a review of the Emission Guidelines. This information is allowing the EPA to assess current practices, emissions, and the potential for additional emission reductions.
The proposed revised Emission Guidelines will ultimately apply to landfills that accepted waste after November 8, 1987,
• Defining closed areas of open landfills.
• Changing the walking pattern for surface emissions monitoring from 30 meters (98 ft) to 25 ft and adding a methane concentration limit of 25 ppm as determined by an integrated reading.
• Addressing wet landfills.
• Monitoring wellhead flow rate.
• Establishing a program for third-party design plan certification.
• Using a portable gas composition analyzer as acceptable alternative to Method 3A or 3C.
The proposed revised Emission Guidelines are expected to significantly reduce emissions of landfill gas and its components, which include methane, volatile organic compounds (VOC), and hazardous air pollutants (HAP). Landfills are a significant source of methane emissions, and in 2013, landfills represented the third largest source of human-related methane emissions in the U.S.
To comply with the emissions limits in the proposed rule, MSW landfill owners or operators are expected to install the least-cost control for collecting and combusting landfill gas. The annualized net cost for the proposed Emission Guidelines is estimated to be $46.8 million (2012$) in 2025, when using a 7 percent discount rate. The annualized costs represent the costs compared to no changes to the current Emission Guidelines (
Installation of a GCCS to comply with the 34 Mg/yr NMOC emissions threshold at open landfills would achieve reductions of 2,770 Mg/yr NMOC and 436,100 Mg/yr methane (about 10.9 million metric tons of carbon dioxide equivalent per year (mtCO
The EPA estimates that the proposal's estimated methane emission reductions and secondary CO
The SC-CH
With the data available, we are not able to provide health benefit estimates for the reduction in exposure to HAP, ozone, and PM
Based on the monetized benefits and costs, the estimated net benefits of the rule are estimated to be $620 million ($2012) in 2025.
This proposed rule addresses existing MSW landfills and associated solid waste management programs. Potentially affected categories include those listed in Table 1 of this preamble.
This table is not intended to be exhaustive, but rather provides a guide for readers regarding entities likely to be regulated by the new subpart. To determine whether your facility would be regulated by this action, you should carefully examine the applicability criteria in proposed 40 CFR 60.32f of subpart Cf. If you have any questions regarding the applicability of the proposed subpart to a particular entity, contact the person listed in the preceding
Clearly mark the part or all of the information that you claim to be CBI. For CBI information in a disk or CD-ROM that you mail to the EPA, mark the outside of the disk or CD-ROM as CBI and then identify electronically within the disk or CD-ROM the specific information that is claimed as CBI. In addition to one complete version of the comment that includes information claimed as CBI, a copy of the comment that does not contain the information claimed as CBI must be submitted for inclusion in the public docket. Information marked as CBI will not be disclosed except in accordance with procedures set forth in 40 CFR part 2.
Do not submit information that you consider to be CBI or otherwise protected through
If you have any questions about CBI or the procedures for claiming CBI, please consult the person identified in the
The docket number for the Emission Guidelines and Compliance Times for Municipal Solid Waste Landfills (proposed 40 CFR part 60, subpart Cf) is Docket ID No. EPA-HQ-OAR-2014-0451. Docket ID No. A-88-09 for related 40 CFR part 60, subparts WWW and Cc contains supporting information.
Please contact Ms. Aimee St. Clair at (919) 541-1063 or at
If a hearing is held, it will provide interested parties the opportunity to present data, views or arguments concerning the proposed action. The EPA will make every effort to accommodate all speakers who arrive and register. Because this hearing, if held, will be at U.S. government facilities, individuals planning to attend the hearing should be prepared to show valid picture identification to the security staff in order to gain access to the meeting room. Please note that the REAL ID Act, passed by Congress in 2005, established new requirements for entering federal facilities. If your driver's license is issued by Alaska, American Samoa, Arizona, Kentucky, Louisiana, Maine, Massachusetts, Minnesota, Montana, New York, Oklahoma or the state of Washington, you must present an additional form of identification to enter the federal building. Acceptable alternative forms of identification include: Federal employee badges, passports, enhanced driver's licenses and military identification cards. In addition, you will need to obtain a property pass for any personal belongings you bring with you. Upon leaving the building, you will be required to return this property pass to the security desk. No large signs will be allowed in the building, cameras may only be used outside of the building and demonstrations will not be allowed on federal property for security reasons.
The EPA may ask clarifying questions during the oral presentations, but will not respond to the presentations at that time. Written statements and supporting information submitted during the comment period will be considered with the same weight as oral comments and supporting information presented at the public hearing. Commenters should notify Ms. St. Clair if they will need specific equipment, or if there are other special needs related to providing comments at the hearings. Verbatim transcripts of the hearing and written statements will be included in the docket for the rulemaking. The EPA will make every effort to follow the schedule as closely as possible on the day of the hearing; however, please plan for the hearing to run either ahead of schedule or behind schedule. A public hearing will not be held unless requested. Please contact Ms. Aimee St. Clair at (919) 541-1063 or at [email protected] to
The Emission Guidelines for MSW landfills were promulgated on March 12, 1996, and subsequently amended on June 16, 1998, February 24, 1999, and April 10, 2000, to make technical corrections and clarifications. Amendments were proposed on May 23, 2002, and September 8, 2006, to address implementation issues, but those amendments were never finalized. On July 17, 2014, the EPA issued an ANPRM for the MSW landfills Emission Guidelines (79 FR 41772). The purpose of that action was to request public input on controls and practices that could further reduce emissions from existing MSW landfills and to evaluate that input to determine if changes to the Emission Guidelines were appropriate. On July 17, 2014, the EPA issued a concurrent proposal for revised NSPS for new MSW landfills (79 FR 41796). In this action, the EPA is proposing a review of and certain changes to the Emission Guidelines to build on progress to date to (1) achieve additional reductions in emissions of LFG and its components, (2) account for changes in size, ownership and age of landfills and trends in GCCS installations, as reflected in new data, (3) provide new options for demonstrating compliance, and (4) to complete efforts regarding unresolved implementation issues. The proposed approaches are consistent with the Methane Strategy developed as part of the President's Climate Action Plan.
In June 2013, President Obama issued a Climate Action Plan that directed federal agencies to focus on “assessing current emissions data, addressing data gaps, identifying technologies and best practices for reducing emissions, and identifying existing authorities and incentive-based opportunities to reduce methane emissions.”
The “Climate Action Plan: Strategy to Reduce Methane Emissions”
The EPA recognized the climate benefits associated with reducing methane emissions from landfills nearly 25 years ago. The 1991 NSPS Background Information Document
LFG is a collection of air pollutants, including methane and NMOC. LFG is typically composed of 50-percent methane, 50-percent CO
VOC emissions are precursors to both PM
In addition to the improvements in air quality and resulting benefits to human health and the non-climate welfare effects discussed above, reducing emissions from landfills is expected to result in climate co-benefits due to reductions of the methane component of LFG. Methane is a potent GHG with a global warming potential (GWP) 28-36 times greater than CO
In 2009, based on a large body of robust and compelling scientific evidence, the EPA Administrator issued the Endangerment Finding under CAA section 202(a)(1).
The 2009 Endangerment Finding documented that climate change caused by human emissions of GHGs threatens the health of Americans. By raising average temperatures, climate change increases the likelihood of heat waves, which are associated with increased deaths and illnesses. While climate change also increases the likelihood of reductions in cold-related mortality, evidence indicates that the increases in heat mortality will be larger than the decreases in cold mortality in the United States. Compared to a future without climate change, climate change is expected to increase ozone pollution over broad areas of the U.S., including in the largest metropolitan areas with the worst ozone problems, and thereby increase the risk of morbidity and mortality. Climate change is also expected to cause more intense hurricanes and more frequent and intense storms and heavy precipitation, with impacts on other areas of public health, such as the potential for increased deaths, injuries, infectious and waterborne diseases, and stress-related disorders. Children, the elderly, and the poor are among the most vulnerable to these climate-related health effects.
The 2009 Endangerment Finding documented that climate change impacts touch nearly every aspect of public welfare. Among the multiple threats caused by human emissions of GHGs, climate changes are expected to place large areas of the country at serious risk of reduced water supplies, increased water pollution, and increased occurrence of extreme events such as floods and droughts. Coastal areas are expected to face a multitude of increased risks, particularly from rising sea level and increases in the severity of storms. These communities face storm and flooding damage to property, or even loss of land due to inundation, erosion, wetland submergence and habitat loss.
Impacts of climate change on public welfare also include threats to social and ecosystem services. Climate change is expected to result in an increase in peak electricity demand, Extreme weather from climate change threatens energy, transportation, and water resource infrastructure. Climate change may also exacerbate ongoing environmental pressures in certain settlements, particularly in Alaskan indigenous communities, and is very likely to fundamentally rearrange U.S. ecosystems over the 21st century. Though some benefits may balance adverse effects on agriculture and forestry in the next few decades, the body of evidence points towards increasing risks of net adverse impacts on U.S. food production, agriculture and forest productivity as temperature continues to rise. These impacts are global and may exacerbate problems outside the U.S. that raise humanitarian, trade, and national security issues for the U.S.
Since the 2009 administrative record concerning the Endangerment Finding closed following the EPA's 2010 Reconsideration Denial, the climate has continued to change, with new records being set for a number of climate indicators such as global average surface temperatures, Arctic sea ice retreat, CO
The EPA has carefully reviewed these recent assessments in keeping with the same approach outlined in Section VIII.A of the 2009 Endangerment Finding, which was to rely primarily upon the major assessments by the USGCRP, IPCC, and the NRC to provide the technical and scientific information to inform the Administrator's judgment regarding the question of whether GHGs endanger public health and welfare. These assessments addressed the scientific issues that the EPA was required to examine were comprehensive in their coverage of the GHG and climate change issues, and underwent rigorous and exacting peer review by the expert community, as well as rigorous levels of U.S. government review.
The findings of the recent scientific assessments confirm and strengthen the conclusion that GHGs endanger public health, now and in the future. The NCA3 indicates that human health in the United States will be impacted by “increased extreme weather events, wildfire, decreased air quality, threats to mental health, and illnesses transmitted by food, water, and disease-carriers such as mosquitoes and ticks.” The most recent assessments now have greater confidence that climate change will influence production of pollen that exacerbates asthma and other allergic respiratory diseases such as allergic rhinitis, as well as effects on conjunctivitis and dermatitis. Both the NCA3 and the IPCC AR5 found that increasing temperature has lengthened the allergenic pollen season for ragweed, and that increased CO
The NCA3 also finds that climate change, in addition to chronic stresses such as extreme poverty, is negatively affecting indigenous peoples' health in the United States through impacts such as reduced access to traditional foods, decreased water quality, and increasing exposure to health and safety hazards. The IPCC AR5 finds that climate change-induced warming in the Arctic and resultant changes in environment (
The NCA3 concludes that children's unique physiology and developing bodies contribute to making them particularly vulnerable to climate change. Impacts on children are expected from heat waves, air pollution, infectious and waterborne illnesses, and mental health effects resulting from extreme weather events. The IPCC AR5 indicates that children are among those especially susceptible to most allergic diseases, as well as health effects associated with heat waves, storms, and floods. The IPCC finds that additional health concerns may arise in low income households, especially those with children, if climate change reduces food availability and increases prices, leading to food insecurity within households.
Both the NCA3 and IPCC AR5 conclude that climate change will increase health risks facing the elderly. Older people are at much higher risk of mortality during extreme heat events. Pre-existing health conditions also make older adults susceptible to cardiac and respiratory impacts of air pollution and to more severe consequences from infectious and waterborne diseases. Limited mobility among older adults can also increase health risks associated with extreme weather and floods.
The new assessments also confirm and strengthen the conclusion that GHGs endanger public welfare, and emphasize the urgency of reducing GHG emissions due to their projections that show GHG concentrations climbing to ever-increasing levels in the absence of mitigation. The NRC assessment
Future temperature changes will depend on what emission path the world follows. In its high emission scenario, the IPCC AR5 projects that global temperatures by the end of the century will likely be 2.6 °C to 4.8 °C (4.7 to 8.6 °F) warmer than today. Temperatures on land and in northern latitudes will likely warm even faster than the global average. However, according to the NCA3, significant reductions in emissions would lead to noticeably less future warming beyond mid-century, and therefore less impact to public health and welfare.
While rainfall may see only small globally and annually averaged changes, there are expected to be substantial shifts in where and when that precipitation falls. According to the NCA3, regions closer to the poles will see more precipitation, while the dry subtropics are expected to expand (colloquially, this has been summarized as wet areas getting wetter and dry regions getting drier). In particular, the NCA3 notes that the western U.S., and especially the Southwest, is expected to become drier. This projection is consistent with the recent observed drought trend in the West. At the time of publication of the NCA, even before the last 2 years of extreme drought in California, tree ring data were already indicating that the region might be experiencing its driest period in 800
Since the 2009 Endangerment Finding, the USGCRP NCA3 and multiple NRC assessments have projected future rates of sea level rise that are 40 percent larger to more than twice as large as the previous estimates from the 2007 IPCC 4th Assessment Report due in part to improved understanding of the future rate of melt of the Antarctic and Greenland ice sheets. The NRC Sea Level Rise assessment projects a global sea level rise of 0.5 to 1.4 meters (1.6 to 4.6 feet) by 2100, the NRC National Security Implications assessment suggests that “the Department of the Navy should expect roughly 0.4 to 2 meters (1.3 to 6.6 feet) global average sea-level rise by 2100,”
In general, climate change impacts are expected to be unevenly distributed across different regions of the United States and have a greater impact on certain populations, such as indigenous peoples and the poor. The NCA3 finds climate change impacts such as the rapid pace of temperature rise, coastal erosion and inundation related to sea level rise and storms, ice and snow melt, and permafrost thaw are affecting indigenous people in the United States. Particularly in Alaska, critical infrastructure and traditional livelihoods are threatened by climate change and, “[i]n parts of Alaska, Louisiana, the Pacific Islands, and other coastal locations, climate change impacts (through erosion and inundation) are so severe that some communities are already relocating from historical homelands to which their traditions and cultural identities are tied.”
Events outside the United States, as also pointed out in the 2009 Endangerment Finding, will also have relevant consequences. The NRC Climate and Social Stress assessment concluded that it is prudent to expect that some climate events “will produce consequences that exceed the capacity of the affected societies or global systems to manage and that have global security implications serious enough to compel international response.” The NRC National Security Implications assessment recommends preparing for increased needs for humanitarian aid; responding to the effects of climate change in geopolitical hotspots, including possible mass migrations; and addressing changing security needs in the Arctic as sea ice retreats.
In addition to future impacts, the NCA3 emphasizes that climate change driven by human emissions of GHGs is already happening now and it is happening in the United States. According to the IPCC AR5 and the NCA3, there are a number of climate-related changes that have been observed recently, and these changes are projected to accelerate in the future. The planet warmed about 0.85 °C (1.5 °F) from 1880 to 2012. It is extremely likely (>95 percent probability) that human influence was the dominant cause of the observed warming since the mid-20th century, and likely (>66 percent probability) that human influence has more than doubled the probability of occurrence of heat waves in some locations. In the Northern Hemisphere, the last 30 years were likely the warmest 30 year period of the last 1,400 years. U.S. average temperatures have similarly increased by 1.3 to 1.9 degrees F since 1895, with most of that increase occurring since 1970. Global sea levels rose 0.19 m (7.5 inches) from 1901 to 2010. Contributing to this rise was the warming of the oceans and melting of land ice. It is likely that 275 gigatons per year of ice melted from land glaciers (not including ice sheets) since 1993, and that the rate of loss of ice from the Greenland and Antarctic ice sheets increased substantially in recent years, to 215 gigatons per year and 147 gigatons per year respectively since 2002. For context, 360 gigatons of ice melt is sufficient to cause global sea levels to rise 1 millimeter (mm). Annual mean Arctic sea ice has been declining at 3.5 to 4.1 percent per decade, and Northern Hemisphere snow cover extent has decreased at about 1.6 percent per decade for March and 11.7 percent per decade for June. Permafrost temperatures have increased in most regions since the 1980s, by up to 3 °C
In addition to the changes documented in the assessment literature, there have been other climate milestones of note. According to the IPCC, methane concentrations in 2011 were about 1,803 parts per billion, 150 percent higher than concentrations were in 1750. After a few years of nearly stable concentrations from 1999 to 2006, methane concentrations have resumed increasing at about 5 parts per billion per year. Concentrations today are likely higher than they have been for at least the past 800,000 years. Arctic sea ice has continued to decline, with September of 2012 marking a new record low in terms of Arctic sea ice extent, 40 percent below the 1979-2000 median. Sea level has continued to rise at a rate of 3.2 mm per year (1.3 inches/decade) since satellite observations started in 1993, more than twice the average rate of rise in the 20th century prior to 1993.
These assessments and observed changes make it clear that reducing emissions of GHGs across the globe is necessary in order to avoid the worst impacts of climate change, and underscore the urgency of reducing emissions now. The NRC Committee on America's Climate Choices listed a number of reasons “why it is imprudent to delay actions that at least begin the process of substantially reducing emissions.”
• The faster emissions are reduced, the lower the risks posed by climate change. Delays in reducing emissions could commit the planet to a wide range of adverse impacts, especially if the sensitivity of the climate to GHGs is on the higher end of the estimated range.
• Waiting for unacceptable impacts to occur before taking action is imprudent because the effects of GHG emissions do not fully manifest themselves for decades and, once manifest, many of these changes will persist for hundreds or even thousands of years.
In the committee's judgment, the risks associated with doing business as usual are a much greater concern than the risks associated with engaging in strong response efforts.
Methane is a precursor to ground-level ozone, a health-harmful air pollutant. Additionally, ozone is a short-lived climate forcer that contributes to global warming. In remote areas, methane is a dominant precursor to tropospheric ozone formation.
The EPA is not statutorily obligated to conduct a review of the Emission Guidelines, but has the discretionary authority to do so when circumstances indicate that it is appropriate. The EPA has determined that it is appropriate to conduct a review of and propose certain changes to the Emission Guidelines due to changes in the size, ownership and age of landfills and the types of MSW landfills with gas collection systems installed since the Emission Guidelines were promulgated in 1996 and the opportunities for significant reductions in methane and other pollutants at reasonable cost. The EPA compiled new information on MSW landfills through data collection efforts for a statutorily mandated review of the NSPS, public comments received on the NSPS proposal, and public comments received on an ANPRM for a review of the Emission Guidelines. This information allowed the EPA to conduct an assessment of current practices, emissions and potential for additional emission reductions. Information received in response to this proposed rule will allow EPA to further refine that assessment.
The purpose of this action is to (1) present the results of EPA's initial review of the Emission Guidelines, (2) propose and take comment on revisions to the Emission Guidelines based on that review, and (3) propose resolution or provide clarification regarding implementation issues that were addressed in prior proposed amendments published on May 23, 2002 (67 FR 36475) and September 8, 2006 (71 FR 53271) as they apply to existing sources. The proposed revisions appear in the proposed 40 CFR part 60, subpart Cf.
Landfills currently subject to 40 CFR part 60, subparts Cc and WWW would be considered “existing” and would ultimately be affected by any changes to the Emission Guidelines resulting from this review. Any source for which construction, modification, or reconstruction commenced on or before July 17, 2014, the date of proposal of new subpart XXX, is an existing source. Under section 111, a source is either new,
Once the EPA receives a complete state plan or plan revision, and completes its review of that plan or plan revision, the EPA will propose the plan or plan revision for approval or disapproval. The EPA will approve or disapprove the plan or plan revision no later than 4 months after the date the plan or plan revision was required to be submitted 40 CFR 60.27(b). The EPA will publish state plan approvals or disapprovals in the
Because many of the landfills currently subject to 40 CFR part 60, subparts Cc and WWW are closed, the EPA is proposing several items to minimize the burden on these closed landfills, as discussed in section VIII.A of this preamble.
The EPA is proposing to add a new subpart Cf to 40 CFR part 60, beginning at 40 CFR 60.30f. Subpart Cf would apply to landfills that have accepted waste after November 8, 1987, and were constructed, reconstructed, or modified on or before July 17, 2014. Proposed subpart Cf in 40 CFR part 60 contains a revision to the NMOC emission threshold for landfills that are not closed and addresses technical and implementation issues for all landfills subject to this subpart.
The EPA is proposing several changes to the Emission Guidelines following its review of the Emission Guidelines and the NSPS for MSW landfills. The EPA reviewed both landfills regulations and considered the current technology, practices, and associated monitoring, recordkeeping, and reporting requirements. The rationale for the following proposed changes is presented in sections V through IX of this preamble.
The EPA has determined that a well-designed and well operated landfill GCCS with a control device capable of reducing NMOC by 98 percent by weight continues to be the best system of emission reduction (BSER) for controlling LFG emissions. Thus, there is no change to the fundamental means of controlling LFG: Proposed 40 CFR part 60, subpart Cf requires landfill owners or operators to install a system to collect the LFG from the landfill and to route the collected gas to a combustion device or treatment system. Landfill owners or operators must submit for approval a site-specific GCCS design plan prepared by a professional engineer. The EPA is proposing 98 percent reduction of NMOC, expressed as a performance level (
The EPA carefully considered whether various emission reduction techniques and BMPs that could improve collection and control of LFG emissions should be considered a component of BSER. As explained in section V.A. of this document, the EPA has concluded that the various emission reduction techniques and BMPs should not be considered to be components of BSER and, therefore, is not proposing to require their use. The EPA believes that the techniques and BMPs can, however, be useful in minimizing emissions in appropriate circumstances.
The EPA undertook an analysis of existing landfills to determine whether applying the existing 40 CFR part 60, subpart Cc and WWW size, emissions, and timing criteria for installing and operating a landfill GCCS to the population of existing MSW landfills remains the preferred approach to implementing BSER. Based on the analysis of the threshold and timing parameters, the EPA is proposing to
The EPA is also considering alternative surface monitoring provisions for 40 CFR part 60, subpart Cf. The alternative provisions would reduce the walking pattern for conducting surface monitoring from 30-meter (98 feet (ft)) intervals to 25-ft intervals. The alternative would also add a methane concentration limit of 25 ppm as determined by integrated surface emissions monitoring, in addition to the instantaneous methane concentration limit of 500 ppm. This alternative would also limit surface monitoring during windy conditions. Under the alternative, the landfill would have to take corrective action if either the integrated or instantaneous limits were exceeded. More information about this approach is provided in sections VI.A and X.B of this preamble.
The EPA is also proposing an alternative site-specific emission threshold determination based on surface emission monitoring for when a landfill must install and operate a GCCS, as described in sections IV.C and VII.A, and when to cap or remove a GCCS, as described in section VIII of this preamble.
The proposal to submit performance test data electronically to the EPA applies only to those performance tests conducted using test methods that are supported by the Electronic Reporting Tool (ERT). A listing of the pollutants and test methods supported by the ERT is available at:
The EPA is proposing an alternative site-specific emission threshold determination for when a landfill must
The EPA recognizes that many landfills subject to proposed subpart Cf are closed. Therefore, the EPA is proposing a separate subcategory for landfills that closed on or before August 27, 2015. These landfills would be subject to a 50 Mg/yr NMOC emission rate threshold, consistent with the NMOC thresholds in subparts Cc and WWW of 40 CFR part 60. These landfills would also be exempt from initial reporting requirements, provided that the landfill already met these requirements under subparts Cc or WWW of 40 CFR part 60. The EPA also solicits comments on an alternative approach which would expand the closed landfill subcategory to include those landfills that close within 13 months after publication of the final emission guidelines.
The EPA also recognizes that many open landfills subject to proposed subpart Cf contain inactive areas that do not produce as much landfill gas. Therefore, the EPA is also proposing an alternative set of criteria for determining when it is appropriate to cap or remove a portion of the GCCS. The proposed alternative criteria for capping or removing the GCCS are: (1) The landfill is closed or an area of an active landfill is closed, (2) the GCCS has operated for at least 15 years or the landfill owner or operator can demonstrate that the GCCS will be unable to operate for 15 years due to declining gas flows, and (3) the landfill owner or operator demonstrates that there are no surface emissions of 500 ppm methane or greater for 4 consecutive quarters. With these provisions, the landfill can employ various technologies or practices to minimize surface emissions and have the flexibility to decommission or permanently cap and remove the GCCS based on site-specific surface emission readings. Note that the EPA is requesting comment on defining closed areas of open landfills as discussed in section X.A of this preamble.
The EPA is proposing a definition of treated landfill gas and treatment systems. Specifically, the EPA proposes to define
The general provisions in 40 CFR part 60 provide that emissions in excess of the level of the applicable emissions limit during periods of SSM shall not be considered a violation of the applicable emission limit
We are proposing to revise the definition of “Modification” and “Household waste” “Solid waste,” and “Sludge” and to add a definition of “Segregated yard waste” to make clear the applicability of proposed 40 CFR part 60, subpart Cf.
The EPA has determined that a well-designed and well operated GCCS that collects the LFG from the landfill and routes the collected gas to a combustion device that reduces NMOC by 98 percent by weight or an outlet concentration of 20 ppmvd of NMOC, as hexane, or to a treatment system that processes the gas for subsequent beneficial use in a process that ensures that such reductions are achieved continues to be BSER for controlling LFG emissions for both new and existing MSW landfills. As discussed in section IX.A of this preamble, LFG energy recovery has environmental benefits in controlling emissions and offsetting conventional energy sources. The BSER determination is based on the EPA's review of the NSPS for new landfills as described in the landfills NSPS proposal at 79 FR 41800-41805, as well as public comments and information received on the proposed NSPS (79 FR 41796) and public input received on both the proposed NSPS and the ANPRM (79 FR 41772) for existing landfills.
The majority of comments on this topic, received in response to the proposed NSPS (79 FR 41796), including those from industry owners and operators, landfill engineering consultants, and trade organizations, as well as input received in response to the ANPRM (79 FR 41772), agreed that a GCCS and 98 percent NMOC destruction represent BSER for MSW landfills.
The EPA is proposing 98 percent reduction of NMOC, expressed as a performance level (
The EPA continues to believe that 98 percent reduction is appropriate because this continues to be the level achievable by demonstrated technologies. Current data are consistent with 98 percent destruction. Nonetheless, in the
Commenters on the NSPS did not submit new data on flare performance. However, one commenter included a statement of a guaranteed 98 percent destruction efficiency from a commonly used flare technology provider at landfills.
One commenter on the proposed landfills NSPS did, however, state that EPA should not consider open flares to be part of the BSER for landfills, given issues with their performance in reducing emissions. The commenter provided several references that identified the difficulty in measuring the performance of flares and poor or questionable flare performance when measurements were made, especially in windy conditions.
Based on the operational flexibilities, open flares offer landfill operators, and the flare design and operational requirements in the general provisions, the EPA is retaining the option for landfills to comply with proposed 40 CFR part 60, subpart Cf using an open
Note that flares at landfills are typically non-assisted and generally have low variability in the flow of LFG. A non-assisted, relatively constant flow of gas means there is nothing to dilute or interrupt the mixture of gas in the combustion zone. Thus, LFG and its components are destroyed more efficiently. In addition, with respect to concerns about operating flares in windy conditions, the EPA has found extremely limited data exists to indicate that wind conditions adversely affect destruction efficiencies of flares. Studies cited regarding wind conditions are based on experiments conducted in laboratory environments using very small diameter flares (4.5 to 6 inches) that are more susceptible to wind than larger diameter flares used at MSW landfills.
Although flaring remains one compliance option for collecting and controlling emissions of landfill gas, the EPA believes that the use of landfill gas to produce energy represents a higher value use and requests comments on whether there are opportunities to incentivize the use of landfill gas for energy production rather than flaring. Thus, the EPA solicits comments on incentive approaches to encourage landfill owners or operators to productively use landfill gas for energy.
In the ANPRM for existing landfills (79 FR 41784), the EPA presented several alternative technologies, including oxidative technologies, that could potentially serve as a component of BSER. The principle of oxidative technologies is the use of methanotrophic bacteria, commonly found in most soils and compost, to oxidize methane into water, carbon dioxide, and biomass. The EPA also presented information on various BMPs that could improve the operation and performance of GCCS and thus achieve additional emission reductions. Such BMPs included installing final cover early to increase gas collection efficiency, connecting the leachate collection and removal system (LCRS) to a GCCS, providing redundant seals on wellheads, installing horizontal collectors to facilitate earlier gas collection (
Commenters generally pointed out the site-specific nature of the various GCCS BMPs. Several commenters disagreed that the EPA should prescribe enhanced wellhead seals in the rule and indicated that landfill operators are already employing site-specific approaches to ensure that wells are properly sealed in order to avoid exceedances of wellhead standards and maintain good gas quality. Regarding connecting to a LCRS, two commenters raised several technical site-specific issues associated with connecting an LCRS to a GCCS. Several commenters indicated that LCRS connections are typically shallow and can introduce ambient air into the GCCS, which could increase the risk of subsurface fire. According to these commenters, to reduce these risks, each individual connection point of an LCRS would need to be evaluated to determine if it was suitable for connection to a GCCS. For cover, several commenters stated that landfill cover materials must meet multiple objectives, including controlling odors, vectors, fires, and litter, shedding moisture to reduce infiltration, and supporting vegetation and compaction. One of the commenters added that Resource Conservation and Recovery Act (RCRA) and state and local regulations govern many of these cover criteria and expressed concerns that cover requirements in the Emission Guidelines could be contradictory to other requirements. These commenters indicated that as landfill owners and operators select cover materials and designs intended to promote methane oxidation, such as biocovers or cover soils, these performance objectives should be taken into consideration.
Other commenters advocated for requiring BMPs including enhanced or duplicate seals on wellheads, connections to LCRS to collect LFG, early final covers, horizontal collectors, and BMPs for dewatering gas collection wells.
With respect to oxidative covers, several commenters mentioned or provided information on articles and other literature that discuss selecting appropriate biocover materials.
Several commenters expressed concern with whether the long-term performance of oxidative control technologies in real-world conditions has been established for controlling landfill methane and NMOC emissions. Several commenters appreciated the EPA's willingness to recognize the role of oxidation in mitigating methane and NMOC emissions and agreed that the use of biocovers or biofilters for landfill methane oxidation is promising but did not recommend requiring oxidative controls in the Emission Guidelines. A couple of these commenters indicated that these technologies are not BSER, one of which specifically noted that biocover technology has not been sufficiently demonstrated to support a regulatory requirement under CAA
The EPA recognizes the site-specific nature of GCCS design and operation and that the effectiveness of any particular BMP, therefore, depends on the site-specific circumstances of a particular MSW landfill. Therefore, while EPA strongly encourages the use of appropriate BMP to ensure the best possible design and operation of each GCCS, EPA does not consider any particular BMPs to constitute BSER and, thus, is not proposing to prescribe the use of GCCS BMPs in proposed 40 CFR part 60, subpart Cf. The EPA continues to believe that BSER remains a well-designed and well-operated GCCS and that while all such systems have certain characteristics in common, what constitutes a well-designed and well-operated GCCS will vary somewhat from landfill to landfill. While we agree with commenters that these alternative technologies and BMPs can achieve additional reductions in some circumstances, the performance, cost, and technical feasibility of these BMPs can vary greatly from site to site as well as from cell to cell even within the same site. Further, designing specific components of a GCCS (
The EPA recognizes that the effectiveness of cover practices, both early installation of final cover and the use of oxidative covers in reducing emissions is also site-specific. Therefore, the EPA does not consider these to constitute BSER and is not proposing to prescribe specific cover practices in proposed 40 CFR part 60, subpart Cf. The timing of final cover installation depends on the filling sequence and cell design of the particular landfill. For biocovers, the applicability is dependent on whether the area is closed or open. The materials allowed to be used for oxidative covers could also vary from site to site depending on state or local yard waste or compost bans, materials most favorable to the local climate, or materials that are best suited to meet multiple site-specific performance objectives in addition to reducing landfill gas emissions. The EPA also agrees with commenters who noted that long-term performance of oxidative covers has not yet been adequately demonstrated in a full-scale industrial setting at a landfill.
Based on the information and public input it received on emission reduction techniques and various BMPs that could improve collection and control of LFG emissions, the EPA proposes to conclude that BSER does not include specific GCCS BMPs, cover practices, or oxidative controls and, therefore, is not proposing to require landfills to adopt those practices in the Emission Guidelines. The EPA does not consider oxidative technologies (biocovers and biofilters) or BMPs to be part of BSER.
Although the EPA is not prescribing BMPs for GCCS or advanced cover practices in proposed 40 CFR part 60, subpart Cf, the EPA expects that two proposed rule flexibilities will encourage and promote more widespread adoption of BMPs and alternative cover technologies. First, the proposed Tier 4 surface monitoring demonstration allows a landfill owner or operator to use site-specific surface methane emissions measurements prior to determining when the installation of a regulatory compliant GCCS is required. (The Tier 4 surface emissions threshold is discussed in section VII.A of this preamble. Tier 4 may also be used to determine when the GCCS can be removed, as discussed in section VIII of this preamble.) Thus, the EPA expects that at least some landfill owners or operators will utilize oxidative cover practices or BMPs such as early gas collection or LCRS connection to minimize surface emissions.
Second, the EPA is proposing to remove the wellhead temperature and oxygen/nitrogen performance requirements and the corresponding requirement to take corrective action upon exceeding one of these parameters, thereby providing flexibility with regard to wellhead operating parameters. (The wellhead operating parameters are discussed in section VI.B of this preamble.) With the proposed wellhead operating parameter flexibility, landfill owners or operators may employ cover practices or GCCS BMPs that are suitable for their sites and GCCS designs, thereby allowing them to collect more LFG and reduce emissions without the risk of exceeding a wellhead operating parameter.
In addition to these two flexibilities, the EPA is requesting comment on other compliance flexibilities to better promote the use of GCCS BMPs that could be used in the final Emission Guidelines. To complement the compliance flexibilities proposed in these Emission Guidelines, the EPA intends to explore the creation of technical assistance documents and other tools or resources for educating the owners or operators of affected landfills and delegated authorities about how GCCS BMPs and oxidative controls can be implemented effectively to achieve additional methane and NMOC emission reductions from landfills.
LFG is a by-product of the decomposition of organic material in MSW under anaerobic conditions in landfills. The amount of LFG created primarily depends on the quantity of waste and its composition and moisture content, as well as the design and management practices at the site. Food waste, yard debris, and other organic materials continue to be the largest component of MSW discarded, with food waste comprising the largest portion. Decreasing the amount of organics disposed in landfills would reduce the amount of LFG generated.
As previously discussed in this section V.A, we are proposing to define BSER as a well-designed, installed and operated GCCS. We are proposing to conclude that organics diversion and source separation are not part of a well-designed, installed and operated GCCS and, therefore, not part of BSER. The EPA does, however, consider organics diversion and source separation advantageous because such practices reduce the amount of LFG generated and, thus, may serve as a useful compliance tool as it may allow landfill owners or operators to postpone the need to install a GCCS.
In the ANPRM for existing landfills (79 FR 41787, July 17, 2014), the EPA solicited input on methods to encourage organics diversion in any proposed revised Emission Guidelines. The EPA received a variety of ideas on how best to encourage diversion.
Many commenters generally recognized that organics diversion could achieve emission reductions from landfills. Although the ANPRM (79 FR 41772) specifically stated EPA was not soliciting comments on mandating organics diversion, many commenters cautioned against an organics diversion mandate in the Emission Guidelines, given the complexity and local nature of waste management. Specific examples of how a Tier 4 emission threshold determination and flexible wellhead operating parameters could encourage more landfills to adopt organics diversion programs were provided, as discussed in sections VI, VII, and VIII of this preamble. Several commenters
The EPA recognizes the emission reduction benefit of organics diversion from landfills. A recent study indicated that modest organics diversion programs could achieve a 9 percent reduction in LFG generation rates, while more aggressive diversion programs could yield up to 18.5 percent reduction.
In the 1996 Landfills NSPS Background Information Document,
In addition to the three compliance flexibilities discussed in sections VI.B (wellhead monitoring), VII.A (Tier 4 emission threshold determination), and VIII.B (criteria for capping or removing a GCCS), the EPA is seeking comment on other compliance flexibilities it should consider when issuing the final Emission Guidelines to encourage more organics diversion. The EPA is also requesting comment on other ways we could structure the guidelines to credit organics diversion.
In response to public input, the EPA is also seeking comment on what, if any, role organics diversion policies or measures could play in an approvable state plan. The EPA must ensure that each state plan establishes requirements for LFG emission controls that are at least as stringent as the Emission Guidelines. We are, therefore, interested in how states might demonstrate that a state plan that contains organics diversion policies and measures is at least as stringent as the Emission Guidelines. The EPA is interested in supporting state organics diversion initiatives and one way of doing this may be to provide flexibility to include such initiatives as a component of an approvable state plan. As previously stated, however, to be approvable, a state plan must be at least as stringent in its effect on LFG as the Emission Guidelines,
To examine the potential impact of changes to the timing of initiating and removing landfill gas collection and control, the EPA updated a dataset of information for landfills, as described below, and applied a model to assess when controls were needed under the baseline control scenario (2.5 million
As discussed at 79 FR 41805 in determining whether to revise the proposed standards of performance for new MSW landfills, the EPA developed a dataset of information for landfills, which included landfill-specific data such as landfill open and closure year, landfill design capacity, landfill design area, and landfill depth. For the regulatory analysis, we approximated the number of landfills that would become subject to the regulation based on size using the reported design capacities, which were provided in units of megagrams. For purposes of rule applicability, size is based on both mass (Mg) and volume (m
The EPA made several significant updates to this original dataset to evaluate the impacts of this proposal. Notably, the EPA updated the technical attributes of over 1,200 landfills based on new detailed data reported to 40 CFR part 98, subpart HH of the Greenhouse Gas Reporting Program (GHGRP). In addition, the EPA consulted with its regional offices, as well as state and local authorities, to identify landfills expected to undergo a modification within the next 5 years. According to the applicability of the proposed subpart XXX, if a landfill commenced construction on its modification after July 17, 2014, it would no longer be subject to the state or federal plans implementing these proposed revisions to the Emission Guidelines; therefore, these landfills were excluded from the impacts analysis conducted for this proposal, and their impacts will be considered as part of the final revisions to the standards of performance for new (and modified) landfills issued under 40 CFR part 60, subpart XXX. After incorporating all of the updates to the inventory and taking out the landfills expected to modify, the revised dataset now has 1,839 existing landfills that accepted waste after 1987
The EPA programmed a Microsoft® Access database (hereinafter referred to as the “model”) to calculate the costs and emission reductions associated with the regulatory options for each of the landfills in the revised dataset. The default parameters for methane generation potential (L
When modeled landfill gas emissions for a particular landfill exceeded the emission rate threshold, the EPA assumed that collection equipment was installed and started operating at the landfill 30 months after first exceeding the threshold (as discussed in the docketed memorandum “Methodology for Estimating Cost and Emission Impacts of MSW Landfills Regulations. 2014”). The EPA also assumed that as the landfill was filled over time, the landfill would expand the GCCS into new areas of waste placement according to an expansion lag time of 5 years for active areas and 2 years for areas that are closed or at final grade. Based on input received during public outreach to small entity representatives (SERs) as well as comments received on the proposed NSPS (79 FR 41796), most modern large landfills do not reach final grade within 2 years and a majority of landfills are complying with the 5 year provision.
Although we are proposing a new Tier 4 option as a site-specific alternative for determining if a landfill has exceeded the regulatory emission threshold (and must install controls) or if a landfill has fallen below the regulatory emission threshold (and can remove or cap controls), the number and types of landfills that could opt to use a Tier 4 option are unknown and could not be incorporated into the impacts calculated in the model. As a result, the number of landfills expected to control under each regulatory option, as well as the estimated emission reductions and costs associated with each regulatory option are based on modeled estimates of landfill gas emissions. To estimate the costs of each regulatory option, the EPA made minor changes to the cost methodology discussed in the landfills NSPS proposal at 79 FR 41805. In this analysis, cost equations were obtained from a recent update to EPA's Landfill Gas Energy Cost Model (LFGcost-Web), version 3.0, which was updated by EPA's Landfill Methane Outreach Program (LMOP) in August 2014. The EPA also updated estimates for surface emission monitoring costs based on revised estimates made available to the EPA since proposal of the NSPS in July 2014.
The capital costs continue to be presented in year 2012 dollars and annualized using an interest rate of 7 percent over the lifetime of the equipment (typically 15 years), or in the case of drill mobilization costs, the length of time between each wellfield expansion. These annualized capital costs were added to the annual operating and maintenance costs estimated by LFGcost-Web. The annualized cost includes capital related to the purchase, installation, operation and maintenance of GCCS, and costs related to testing and monitoring.
For certain landfills that were expected to generate revenue by using the LFG for energy, the EPA also estimated LFG energy recovery rates and associated costs to install and operate the energy recovery equipment as well as the revenue streams from the recovered energy. These revenues were subtracted from the annualized capital and operating and maintenance costs at each landfill in order to obtain a net cost estimate for each option in each year. The emission reduction and cost and revenue equations and assumptions are detailed in the docketed memoranda, “Updated Methodology for Estimating Cost and Emission Impacts of MSW Landfills Regulations. 2015” and “Updated Methodology for Estimating Testing and Monitoring Costs for the MSW Landfill Regulations. 2015.”
The EPA estimates that the potential uncontrolled emissions from the approximately 1,800 landfills in its regulatory analysis dataset (as explained in section V.B of this preamble) are approximately 69,700 Mg NMOC and 11.0 million Mg methane (275 million mtCO
Looking beyond the modeled dataset, the Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2013 shows a growth in uncontrolled emissions from MSW landfills, from 205.4 teragrams (Tg) CO
To estimate the emission reductions, the EPA applied the current design capacity and NMOC emission rate thresholds in the MSW landfills regulations, and the time allowed for installing, expanding and removing the GCCS to the modeled emission estimates discussed in section V.B of this preamble.
Table 2 of this preamble summarizes the reductions anticipated to be achieved in 2025 as a result of 40 CFR part 60, subpart WWW and the federal and state plans implementing the Emission Guidelines. This table reflects the current baseline level of control at existing landfills: Landfills greater than or equal to 2.5 million Mg and 2.5 million m
The Emission Guidelines in the baseline are estimated to require control at 574 of the 989 affected landfills in 2025 and achieve reductions of 57,300 Mg/yr NMOC and 9.0 million Mg/yr methane (226 million mt/yr CO
Landfill owners or operators collect LFG for a variety of reasons: To control odor, to minimize fire and explosion hazards, to recover LFG to be used for energy recovery, to sell carbon credits, and to comply with local, state, or federal air quality standards. This section of this proposed action discusses several non-EPA programs of which the EPA is aware. These reductions complement the reductions achieved by the current NSPS and Emission Guidelines framework.
The EPA is aware that some state or local ordinances require LFG combustion. The number of landfills controlling under these ordinances is unknown and is not factored into the incremental impacts analysis for this rule. The EPA is also aware that other states have rules regulating LFG combustion for odor control or safety reasons, which may be less comprehensive than the requirements of a GCCS operated in accordance with the NSPS and emission guideline requirements.
Many of these systems may have been installed to recover energy and generate revenue through the sale of electricity or LFG. Some landfills with voluntary systems may also receive revenues as a result of the creation of carbon credits. Data from the Climate Action Reserve indicates that more than 115 LFG capture projects in 36 states have been issued credits known as Climate Reserve Tonnes (CRTs).
To estimate the number of landfills that may be controlling LFG emissions voluntarily, the EPA evaluated the most current data available and compared the list of landfills that are modeled to have installed a GCCS in 2014 in the NSPS/Emission Guidelines dataset to the list of landfills that are reported to have a GCCS installed in the LMOP or subpart HH GHGRP databases. While the NSPS/Emission Guidelines dataset estimates that approximately 620 landfills have installed controls to meet the requirements of the NSPS or an approved state plan or federal plan implementing the Emission Guidelines, the LMOP and GHGRP databases show approximately 330 additional landfills as having installed controls, resulting in approximately 950 landfills estimated to have a GCCS installed in 2014.
The EPA considered several factors when determining which control options would represent BSER. This section of the preamble describes those control options, which include varying the design capacity threshold, varying the NMOC emission rate threshold, and varying the time allowed to install and then expand the GCCS. To examine these options, the EPA ran several permutations of various control options on the original dataset developed for the July 2014 NSPS proposal. Each regulatory option assessed variations in the design capacity and/or emission rate thresholds, as well as changes to the initial lag time and expansion lag time. The “initial lag time” is the time period between when the landfill exceeds the emission rate threshold and when controls are required to be installed and started up (30 months in 40 CFR part 60, subparts Cc and WWW). The “expansion lag time” is the amount of time allotted for the landfill to expand the GCCS into new areas of the landfill (5 years for active areas and 2 years for areas that are closed or at final grade in 40 CFR part 60, subpart WWW).
Some options adjusted a single threshold in isolation; for example, reducing the NMOC emission threshold to between 34 and 40 Mg/yr while keeping the design capacity threshold constant at 2.5 million Mg. Other options adjusted multiple control parameters simultaneously, taking into account the relationship between the parameters. For example, recognizing that NMOC emissions are a function of waste-in-place, some options that significantly reduced the NMOC emission threshold also reduced the design capacity thresholds to 2.0 million Mg to avoid situations where the NMOC emission threshold would be exceeded long before the design capacity threshold.
In addition to adjusting design capacity and emission control thresholds, other preliminary model runs varied the initial and/or expansion lag times. These variations estimated the impacts of requiring landfill owners or operators to install or expand gas collection systems more quickly after crossing each modeled NMOC emission threshold.
In 2013, the EPA presented different model runs during Federalism consultations and small entity outreach that represented the range of variation in both the threshold and lag time parameters. For the options presented, small entity representatives (SERs) and Federalism consultation participants provided feedback to the EPA, which included implementation concerns with varying certain parameters as part of the Emission Guidelines review, as discussed in the following sections. The EPA also received comments on varying certain parameters in response to its July 2014 NSPS proposal and ANPRM for Emission Guidelines at MSW landfills (79 FR 41772) and conducted a subsequent round of Federalism consultations and small entity outreach in 2015. The EPA considered these concerns and comments received on the July 2014 NSPS proposal and ANRPM when developing a revised set of regulatory options in this proposal.
For this proposal, the EPA considered two different design capacity thresholds: No change from the current regulatory baseline of 2.5 million Mg and 2.5 million m
The EPA did not consider an option to remove the design capacity criteria for this proposal so that all landfills would be affected sources no matter their size, because of the burdens of permitting and reporting at small landfills as discussed below and at 79 FR 41782. If the EPA were to remove the design capacity threshold, a significant number of additional landfills would be subject to the rule. Out of the approximately 1,800 existing landfills in the revised dataset, approximately 850 have a design capacity of less than 2.5 million Mg. Without a design capacity threshold, the NMOC emission rate would be the only criterion for installing controls. Thus, these 850 landfills would be required to begin calculating and reporting their NMOC emission rate. They would also be required to obtain a Title V permit. This would present a significant burden on both regulated landfills and delegated permitting authorities, which must be evaluated in light of potential emissions reductions.
The EPA did not analyze control options for landfills with landfill design capacities less than 2.0 million Mg in the model. Based on the revised dataset, 571 of the 623 closed landfills (91.6 percent) have a design capacity less than 2.0 million Mg. Lowering the design capacity below 2.0 million Mg would cause a large number of closed landfills to become subject to regulatory requirements including annual NMOC reporting requirements and Title V permitting requirements. Additionally depending on NMOC emission rates, a number of these landfills may also be required to install GCCS despite the fact that many of these landfills have been closed for many years and are on the downside of their gas production curve. The EPA concludes lowering the design capacity threshold below 2.0 million Mg would add regulatory requirements with minimal environmental benefit. The EPA also notes that closed landfills may have limited access to additional revenue because they are no longer collecting tipping fees and the cost for GCCS and regulatory compliance were not factored into their closure plans, they may have poor or incomplete records for estimating landfill gas emissions, and they are less likely to be permitted.
Several commenters from state agencies expressed concerns with the permitting and reporting burdens on smaller landfills and advised the EPA to retain the current design capacity threshold. Another state agency noted that MSW landfills with a design capacity greater than 0.38 million m
Two commenters advocated for reducing or eliminating the design capacity criteria, referencing the state of California Landfill Methane Rule
Based on a review of GCCS data reported in its dataset, the EPA estimates that over 900 landfills in its revised dataset have installed a GCCS for either voluntary or regulatory reasons. Of these, 17 percent of landfills with a capacity less than 2.0 Million Mg report having a GCCS installed; 47 percent of landfills with a capacity between 2.0 million Mg and 2.5 million Mg have a GCCS installed; and 76 percent of landfills with a capacity of 2.5 Million Mg or greater have a GCCS installed.
When the EPA promulgated the 2.5 million Mg and 2.5 million m
Assuming an NMOC emission threshold level of 34 Mg/yr, reducing the design capacity from 2.5 million Mg and 2.5 million m
The EPA does not believe that the additional burden on small entities and the disproportionate impact on publicly-owned landfills can be justified in light of the limited additional reduction in overall emissions and is, therefore, not proposing any changes to the current design capacity threshold of 2.5 million Mg and 2.5 million m
For this proposal, the EPA considered two alternative NMOC emission thresholds: 40 Mg/yr and 34 Mg/yr. The EPA recognizes that NMOC emissions are site specific, varying widely from landfill to landfill and understands that a majority of landfills currently affected by the federal and state plans implementing the Emission Guidelines conduct Tier 2 testing in order to refine their NMOC emission estimates before installing a GCCS. This proposal also allows a new site-specific Tier 4 alternative to determine when a landfill must install a GCCS, as discussed in sections IV.C and VII.A of this preamble.
Despite these variations in NMOC emissions, results from the model show that a lower NMOC emissions threshold could accelerate the schedule for installing GCCS at existing landfills and also increase the number of existing landfills required to install controls, thereby achieving additional reductions of NMOC emissions.
The EPA proposed on July 17, 2014 a lower NMOC emission threshold in the NSPS (40 Mg/yr) and discussed this alternative in the ANPRM (79 FR 41772) and several nongovernmental organizations (NGOs) and a local government entity commented in support of a reduction in the NMOC emission threshold. One state agency also provided examples of existing landfills controlling emissions in its state with estimated NMOC emission rates as low as 8.1 Mg/yr.
Two commenters expressed concern about whether landfills planning to install controls based on the current threshold of 50 Mg/yr would be financially ready to install controls at an earlier time. Other commenters expressed concern about whether landfills that have closed and decommissioned their GCCS should be pulled back into control requirements if their emissions fall between the current 50 Mg/yr threshold and a more stringent NMOC emission threshold. These commenters recommended that EPA exempt these landfills from more stringent control requirements. One of the commenters added that it would be costly to re-install or refurbish a previously shutdown system and noted that the system would likely operate for only a few more years before it once again fell below the more stringent NMOC emission threshold.
Other commenters expressed concerns that lowering the NMOC threshold would jeopardize carbon credit revenues expected from landfills emitting between 40 and 50 Mg/yr NMOC that were planning on voluntarily installing a GCCS. A state agency also expressed concern about the additional burden to delegated authorities of managing a larger group of landfills. Another state agency expressed concerns that landfills in arid areas will have difficulty continuously operating a flare at landfills with lower quality gas that emit between 40 and 50 Mg/yr. Another commenter indicated that older and closed landfills will struggle to maintain continuous operation of their flare at a lower NMOC emission threshold and will need to operate the flare with a supplemental fossil fuel.
Because of concerns with GCCS operations at landfills that have closed, the EPA evaluated whether the lower NMOC thresholds of 34 and 40 Mg/yr should apply to this subset of landfills, as discussed in section VIII.A of this preamble and presented in Table 3 of this preamble. Because of concerns about areas with low gas quality, the EPA is proposing changes to address closed or low-gas-quality areas, including changes to the criteria for capping or removing a GCCS, and providing for the use of site-specific surface emissions monitoring measurements to indicate area-specific LFG emissions, as discussed in section VIII.B of this preamble.
As shown in Table 3 of this preamble, the incremental cost to control NMOC at open landfills at a threshold of 34 Mg/yr NMOC is $17,000/Mg NMOC and $4.3/mtCO
In its revised regulatory options analysis for this proposal, the EPA did not model the impacts from any regulatory options that reduced the initial or expansion lag times. To a great extent, this decision was based on our consideration of the numerous implementation and cost concerns raised by SERs and Federalism consultation participants as discussed at 79 FR 41807,
One state agency commented that shortening the current initial lag time would not allow sufficient time to develop and approve the GCCS design plan, obtain the necessary permit, and construct the GCCS. The commenter added that one unintended consequence of shortening the initial lag time could be the inhibition of the beneficial reuse of landfill gas, since a shorter lag time may not allow time to design and approve a more complex landfill gas energy recovery system. Commenters representing affected landfills also expressed concerns that current administrative and construction lead times would make shorter lag times difficult.
Several landfill owners or operators and a state authority agreed with costs and operational and safety concerns described at 79 FR 41807 associated with increasing the number of wells in active areas as a result of shorter initial or expansion lag times. One commenter provided detailed information on costs to install and repair wells in active areas, which the commenter estimated to be between two and three times more expensive than wells installed in areas at final grade. This commenter added that 43 percent of the wells installed during 2014 were replacement wells that had to be installed as a result of damage to existing wells resulting from ongoing activities in active areas and noted that shortened lag times would only increase the number of replacement wells required. In addition to the damage to wells from filling operations, one commenter added that vertical wells in active areas require additional lateral collection pipes to be installed on rather flat slopes that are susceptible to condensate blockage and must also be replaced more frequently. Similarly, two commenters were concerned whether horizontal collectors could universally meet the need for shorter lag times in light of the susceptibility of flooding of the horizontal designs and the inability to dewater these wells with pumps.
Several commenters recognized the benefit of earlier GCCS installation, but these commenters also discussed aerobic conditions in active areas and other factors affecting gas quality that in turn create exceedances of wellhead monitoring requirements for pressure, temperature, and oxygen/nitrogen. They noted that few states have accommodated flexible monitoring alternatives for early collection systems. One state authority believed that site-specific factors other than the regulatory-driven lag times, such as safety or odor control, are already achieving earlier installation of GCCS. Three other commenters urged EPA to include early collection requirements in the proposed Emission Guidelines. One of these commenters indicated that the requirement to promote early collection could be flexible instead of a rigid adjustment to the lag times. For the reasons presented in this section as well as those detailed at 79 FR 41807, the EPA is not proposing to shorten the initial or expansion lag times in the revised Emission Guidelines. However, the EPA is requesting comment on whether the regulation should require that the GCCS design plan contain a description of early gas collection measures or best management practices, in order for the reviewing professional engineer or the Administrator to ensure that emissions are minimized. The EPA is also taking comment on whether the monitoring in the rule should be strengthened to require GCCS to be expanded in a site-specific manner as long as surface emission monitoring limits in all areas of the landfill were maintained at all times, similar to the approach taken in the California Landfill Methane Rule (LMR).
When determining which control options would represent BSER, the EPA considered several factors: The implementation considerations identified earlier in this section of this preamble; and the incremental emission reductions, cost, and co-benefits that would be achieved beyond the baseline.
The EPA compared the annualized net cost and emission impacts in 2025 of three different regulatory options to the annualized net costs and emission impacts in 2025 of the baseline. The EPA analyzed numerous iterations of alternate control and reporting thresholds and presented potential control options to SERs and Federalism consultation participants, as described in section V.D of this preamble. After considering feedback from the SERs and Federalism consultation participants, as well as comments received on the July 2014 NSPS proposal and ANPRM (79 FR 41772), the EPA selected for consideration three regulatory alternatives as presented in Table 3 of this preamble. Table 3 summarizes the incremental impacts of each control option, when compared to the baseline. The table shows the NMOC and methane emission reductions and
Based on the characteristics of the landfills, between approximately 60 and 160 additional landfills would be required to install controls in 2025. In addition to increasing the total number of landfills that would control their emissions, the schedule for installing controls would be accelerated for many landfills in years prior to 2025 because the landfill would exceed the lower thresholds of 34 or 40 Mg/yr NMOC earlier than the baseline, and in turn begin collecting and destroying landfill gas emissions earlier.
If the EPA were to reduce the NMOC threshold to 40 Mg/yr at open landfills while retaining a 2.5 million Mg and 2.5 million m
The wide range in the magnitude of emission reductions among pollutants is due to the composition of landfill gas: NMOC represents less than 1 percent of landfill gas, while methane represents approximately 50 percent. CO
In terms of cost effectiveness, the overall dollar-per-Mg cost for NMOC reductions under the baseline is $5,100 per Mg NMOC and $32.3 per Mg methane as presented in Table 3 of this
Reducing the NMOC threshold from the baseline-level of 50 Mg/yr to 34Mg/yr at open landfills would affect 106 more landfills in 2025 and would achieve an estimated 4.8 percent additional reduction in emissions of NMOC and methane compared to the baseline. These additional reductions can be achieved at very similar cost effectiveness to an NMOC threshold of 40 Mg/yr, but a level of 34 Mg/yr would achieve almost 60 percent more reductions than a level of 40 Mg/yr. In addition, the proposal is expected to result in the net reduction of 238,000 Mg CO
Further, this proposal would tighten the control device removal criteria, requiring that the controls would have to stay on until three successive tests for NMOC emissions were below the NMOC emission threshold of 34 Mg/yr instead of 50 Mg/yr, unless the landfill can demonstrate that its surface emissions are low, as discussed in section VIII.B of this preamble. Depending on the waste-in-place of the landfill at closure and other site-specific factors (
Reducing the NMOC threshold also recognizes the opportunity to build upon progress to date and achieve even more reductions of landfill gas and its components, consistent with the President's Methane Strategy as discussed in section III of this preamble. Landfill gas generated from established waste (waste that has been in place for at least a year) is typically composed of roughly 50 percent methane and 50 percent CO
The EPA is not proposing to reduce the design capacity in conjunction with a reduction in the NMOC emission threshold. As discussed in section VI.E of this preamble, this option achieves only modest additional reductions (less than one percent more than the proposed option 2.5/34), but has a disproportionate impact on small entity- and municipally-owned sites, and closed landfills that are on the downward trend of generating landfill gas. Reducing the design capacity would also pose substantial burden on delegated authorities because these small entity- and municipally- owned landfills are not affected by the currently promulgated NSPS or Emission Guidelines.
The intent of the surface monitoring provision in the existing Emission Guidelines is to maintain a tight cover that minimizes the migration of emissions through the landfill surface. Quarterly surface emissions monitoring indicates whether the cover and gas collection system are working properly. In addition to the proposed surface emission provisions discussed here, the EPA is also seeking comment on additional enhancements to surface emissions monitoring in section X.B of this preamble.
Commenters both supported and opposed monitoring every cover penetration. Several commenters, including two state/local agencies and one environmental organization supported monitoring every cover penetration. The state agency noted that seals around penetrations can be compromised as a result of settlement, separation from the barrier layers or boot materials, and cracking of cover soils tied into penetrations, thus, leading to detections of landfill gas during surface monitoring as reported by field staff. Several commenters opposed the requirement to monitor every cover penetration, citing significant additional cost with no or limited environmental benefit. In proposed 40 CFR part 60, subpart Cf, we are reiterating the position in the current regulation that landfills must monitor all cover penetrations and openings within the area of the landfill where waste has been placed and a gas collection system is required. Specifically, landfill owners or operators must conduct surface monitoring at 30-meter intervals and where visual observations indicate elevated concentrations of landfill gas. The EPA maintains that cover penetrations can be observed visually and are clearly a place where gas would be escaping from the cover, so monitoring of them is required by the regulatory language. The regulatory language gives distressed vegetation and cracks as an example of a visual indication that gas may be escaping, but this example does not limit the places that should be monitored by landfill staff or by enforcement agency inspectors. Thus, consistent with the EPA's historical intent and interpretation, the landfill owner or operator must monitor any openings that are within an area of the landfill where waste has been placed and a gas collection system is required.
The operational standards of the current Emission Guidelines are to operate each interior wellhead in the collection system with a negative pressure (vacuum), a landfill gas temperature less than 55 °C and with either a nitrogen level less than 20 percent or an oxygen level less than 5 percent. Since 1996, when the rules were originally promulgated, the EPA has heard concerns from both regulated entities and implementing authorities regarding the implementation of the operational standards for temperature and oxygen/nitrogen at wellheads. The EPA received feedback during 2013 and 2014 from SERs and Federalism consultation participants expressing concern that the wellhead standards were overly prescriptive. In the July 17, 2014 proposed NSPS (79 FR 41821) and the ANPRM for the Emission Guidelines (79 FR 41788), the EPA discussed whether these parameters should be adjusted in order to provide monitoring flexibility for landfills while also ensuring that the GCCS were well operated. The EPA also requested comment on what types of landfills may be eligible for adjustments to these wellhead standards; for example, the EPA asked whether only small entities, or landfills with energy recovery projects should benefit from this flexible monitoring.
In response to the July 2014 proposed NSPS (79 FR 41796) and ANPRM (79 FR 41772), many commenters questioned the need for the current wellhead operating standards for monitoring pressure, temperature, and oxygen or nitrogen to assess whether the GCCS was operating effectively.
Commenters asserted that the wellhead monitoring parameters are poor indicators of landfill fires or inhibited decomposition and impede proper operation of the collection system without providing any of the expected benefits. They also explained that landfill operators typically respond to high temperature and oxygen/nitrogen readings by reducing flow from the well or expanding the gas collection system. They explained that both approaches can have unintended and harmful consequences, including exacerbating a fire, and reducing the collection efficiency of the GCCS. In addition, they asserted that expanding a GCCS in an area with poor gas quality or quantity does not assist with achieving additional reductions. Commenters emphasized the difficulty of meeting the wellhead standards in areas of the landfill with declining gas flowrates or gas quality, which is more common in older or closed areas of the landfill. Several commenters stated that landfill owners already have inherent incentives to minimize fire risks in order to protect significant investments in GCCS and energy recovery infrastructure.
It was also pointed out that gas quality and quantity can vary widely from different systems and at different times within the same system, which is why horizontal collectors and leachate system components are not designed to meet the 40 CR part 60, subpart Cc and WWW operating parameters for pressure, temperature, and nitrogen/oxygen concentration. Information from a state agency indicated that some intake of ambient air is likely with leachate collectors and suggested that operators should have flexibility to decide the balance between gas flow and oxygen intake and on whether to cease extracting landfill gas or use another method. The information provided further indicated that the time delay associated with modifying a GCCS design plan or getting approval for higher operating values (HOVs) is problematic when applied to collector pipes used for seep and odor control, since operators must make these changes more quickly for safety reasons.
The EPA also received input explaining the benefits of early gas collection, such as fewer emissions and reduced odors.
Commenters representing industry, state government, the SBA Office of Advocacy, and a trade organization called on the EPA to remove temperature and oxygen/nitrogen wellhead operating parameters from Emission Guidelines for all landfills. These commenters were all in agreement that negative pressure and surface monitoring can assure proper GCCS operation. One commenter noted that landfills with energy recovery projects will continue to monitor wellhead parameters to ensure proper equipment operation and maximize revenue from energy sales, without requiring the monitoring and reporting of these parameters under the Emission Guidelines. Another commenter noted that the regulations should provide some flexibility to accommodate declining gas generation that facilities will experience as a result of local diversion initiatives.
Two state agencies requested that the wellhead operating parameters of temperature and oxygen/nitrogen merely serve as guidance to provide flexibility, particularly to small entities. One of the commenters provided an example of monitoring requirements in its state regulation, which exempts supplemental and/or temporary odor and gas control system components (
Two commenters requested that temperature and oxygen/nitrogen monitoring requirements be continued while maintaining current surface methane monitoring methods. A state agency noted that wellhead monitoring can identify subsurface biological and chemical reactions that can present a safety hazard and cannot be detected by surface emission monitoring only. An environmental organization explained that wellhead monitoring provides indicators of conditions that could lead to subsurface fires, release massive volumes of HAP, and cause terrible odors and was concerned that removing these requirements prevents the landfill and the implementing authorities from identifying early indicators of potential problems. The commenter explained that landfill owners may have difficulty meeting the requirements due to improper site management and failure to maintain tight seals, leading to too much air intake. One city also advocated for more stringent monitoring in order to more proactively identify odors or other operational concerns with a GCCS.
Based on public comments, input from small entities, and our own analysis of available information, the EPA is proposing to remove the requirement to meet operational standards for temperature and nitrogen/oxygen at wellheads and is thus also proposing to remove the corresponding requirement for corrective action for exceedances of these parameters. To ensure a well-designed and well-operated GCCS that minimizes surface emissions, the EPA is proposing to use a combination of GCCS design and approval requirements as discussed in section VI.C of this preamble, landfill surface emission monitoring requirements as discussed in section VI.A of this preamble, and continued maintenance of negative pressure at wellheads. Based on the feedback provided by commenters and our analysis of available information, the
While the EPA is proposing to remove the requirement to meet operational standards for temperature and nitrogen/oxygen, the EPA is proposing that landfill owners or operators continue monthly monitoring and recordkeeping of the wellhead temperature and oxygen/nitrogen values, consistent with operational guidance documents and best practices for operating a GCCS in a safe and efficient manner.
The requirement to maintain negative pressure at each wellhead ensures that gas is being routed to a GCCS that was designed and built in accordance with a GCCS design plan that has been approved by a professional engineer. The EPA believes these wellhead standards, together with the surface emission monitoring requirements, are effective and limit the possibility of surface emissions of LFG. This approach also allows landfills and state regulators the time and flexibility to determine the appropriate response for adjusting wellfield operations, as needed, without imposing overly prescriptive requirements. This approach also provides increased flexibility for landfills to install supplemental and temporary gas collection components to achieve additional reductions of LFG without the risk of exceeding oxygen/nitrogen or temperature operational standards.
The EPA is proposing criteria for when an affected source must update its design plan and submit it to the implementing authority for approval. We are proposing that a revised design plan must be submitted as follows: (1) Within 90 days of expanding operations to an area not covered by the previously approved design plan, and (2) prior to installing or expanding the gas collection system in a manner other than as described in a previously approved design plan.
The EPA is proposing site-specific design plan review and approval procedures that recognize the unique site-specific topography, climate, and other factors affecting the design of the GCCS. However, the EPA solicits comment on ways to streamline the design plan submission and approval procedures as part of its review of the Emission Guidelines. Examples of streamlining may include the potential development of a process by which approved alternative operating parameters could be automatically linked to updates of design plans or development of a process by which alternative operating parameters and updated design plans could be approved on a similar schedule.
We have included provisions in proposed 40 CFR part 60, subpart Cf (40 CFR 60.36f(a)(3)) to clarify our intent that agency approval of corrective action timelines is required only if a landfill does not fix an exceedance in 15 days and is unable to or does not plan to expand the gas collection system within 120 days. The EPA is clarifying that “expansion” of the GCCS means a permanent change that increases the capacity of the GCCS, such as increasing the size of header pipes, increasing the blower sizes and capacity, and increasing the number of wells. Excluding system expansion, all other types of corrective actions expected to exceed 15 calendar days should be submitted to the agency for approval of an alternate timeline. In addition, if a landfill owner or operator expects the system expansion to exceed the 120-day allowance period, it should submit a request and justification for an alternative timeline. We have not proposed a specific schedule for submitting these requests for alternative corrective action timelines because investigating and determining the appropriate corrective action, as well as the schedule for implementing the corrective action, will be site specific and depend on the reason for the exceedance. We clarify that a landfill should submit an alternative timeline request as soon as possible (
To address implementation concerns associated with the time allowed for corrective action, the EPA requests comment on an alternative that extends the requirement for notification from 15 days to as soon as practicable, but no later than 60 days from when an exceedance is identified. Many requests for an alternative compliance timeline express the need for additional time to make necessary repairs to a well that requires significant construction activities. Extending the time period to as soon as practicable, but no later than 60 days, may reduce the burden associated with the approval of an alternative timeline and ensure
In this proposal, the EPA is describing a process to increase the ease and efficiency of performance test data submittal while improving data accessibility. Specifically, the EPA is proposing that owners or operators of MSW landfills submit electronic copies of required performance test and performance evaluation reports by direct computer-to-computer electronic transfer using the EPA-provided software. The direct computer-to-computer electronic transfer is accomplished through the EPA's Central Data Exchange (CDX) using the Compliance and Emissions Data Reporting Interface (CEDRI). The CDX is the EPA's portal for submittal of electronic data. The EPA-provided software is called the Electronic Reporting Tool (ERT), which is used to generate electronic reports of performance tests and evaluations. The ERT generates an electronic report package that will be submitted using the CEDRI. The submitted report package will be stored in the CDX archive (the official copy of record) and the EPA's public database called WebFIRE. All stakeholders will have access to all reports and data in WebFIRE and accessing these reports and data will be very straightforward and easy (see the WebFIRE Report Search and Retrieval link at
The proposal to submit performance test data electronically to the EPA applies only to those performance tests conducted using test methods that are supported by the ERT. The ERT supports most of the commonly used EPA reference methods. A listing of the pollutants and test methods supported by the ERT is available at
We believe that industry would benefit from this proposed approach to electronic data submittal. Specifically, by using this approach, industry will save time in the performance test submittal process. Additionally, the standardized format that the ERT uses allows sources to create a more complete test report resulting in less time spent on data backfilling if a source failed to include all data elements required to be submitted. Also through this proposal, industry may only need to submit a report once to meet the requirements of the applicable subpart because stakeholders can readily access these reports from the WebFIRE database. This also benefits industry by cutting back on recordkeeping costs as the performance test reports that are submitted to the EPA using CEDRI are no longer required to be retained in hard copy, thereby, reducing staff time needed to coordinate these records.
Since the EPA will already have performance test data in hand, another benefit to industry is that fewer or less substantial data collection requests in conjunction with prospective required residual risk assessments or technology reviews will be needed. This would result in a decrease in staff time needed to respond to data collection requests.
State, local, and tribal air pollution control agencies will also benefit from having electronic versions of the reports they are now receiving because they will be able to conduct a more streamlined and accurate review of electronic data submitted to them. For example, the ERT would allow for an electronic review process, rather than a manual data assessment, making review and evaluation of the source provided data and calculations easier and more efficient. In addition, the public will also benefit from electronic reporting of emissions data because the electronic data will be easier for the public to access. How the air emissions data are collected, accessed, and reviewed will be more transparent for all stakeholders.
One major advantage of the proposed submittal of performance test data through the ERT is a standardized method to compile and store much of the documentation required to be reported by this rule. The ERT clearly states what testing information would be required by the test method and has the ability to house additional data elements that might be required by a delegated authority.
In addition, the EPA must have performance test data to conduct effective reviews of CAA section 111 standards, as well as for many other purposes, including compliance determinations, emission factor development, and annual emission rate determinations. In conducting these required reviews, the EPA has found it ineffective and time consuming, not only for us, but also for regulatory agencies and source owners or operators, to locate, collect, and submit performance test data. In recent years, stack testing firms have typically collected performance test data in electronic format, making it possible to move to an electronic data submittal system that would increase the ease and efficiency of data submittal and improve data accessibility.
A common complaint from industry and regulators is that emission factors are outdated or not representative of a particular source category. With timely receipt and incorporation of data from most performance tests, the EPA would be able to ensure that emission factors, when updated, represent the most current range of operational practices. Finally, another benefit of the proposed data submittal to WebFIRE electronically is that these data would greatly improve the overall quality of existing and new emissions factors by supplementing the pool of emissions test data for establishing emissions factors
In summary, in addition to supporting regulation development, control strategy development, and other air pollution control activities, having an electronic database populated with performance test data would save industry, state/local/tribal agencies, and the EPA significant time, money, and effort while also improving the quality of emission inventories, air quality regulations, and enhancing the public's access to this important information.
The EPA is proposing an emission threshold determination based on site-specific surface emissions monitoring (SEM) that provides flexibility for when a landfill must install and operate a GCCS. If the owner or operator limits landfill surface methane emissions and can demonstrate that those emissions are below 500 ppm methane for 4 consecutive quarters, then the requirement to install a GCCS is not triggered even though estimates using Tiers 1, 2, and/or 3 may show that the landfill's annual NMOC emissions have exceeded the regulatory threshold. In
The idea to measure site-specific surface emissions to help determine the timing of GCCS installation was presented while the EPA was conducting outreach with small entities during its review of the landfills regulations in 2014. Small entities recommended a new Tier 4 surface emission demonstration to allow increased flexibility for landfills that exceed modeled NMOC emission rates to demonstrate that site-specific methane emissions are actually low prior to being required to install a GCCS. In addition, the Environmental Defense Fund (EDF) presented the idea of a surface concentration threshold as one of many potential alternatives to increase emission reductions from landfills in its January 2013 whitepaper.
Many commenters, representing both industry and environmental interests, supported the Tier 4 SEM approach for determining when a GCCS must be installed. These commenters stated that the option to conduct site-specific measurements using SEM is a more accurate indication of when gas collection is necessary to reduce emissions, compared to modeled emission rates. However, one commenter on the NSPS proposed rule opposed the inclusion of a Tier 4 option for new landfills, stating that it allows a subset of new landfills to delay methane capture requirements when these landfills will be required to install a GCCS in the future and should have a GCCS designed and installed during landfill construction. Other commenters expressed concern about state agencies lack of experience and time to determine whether Tier 4 monitoring requires a GCCS to be installed and requested guidance for Tier 4 implementation procedures.
Many commenters identified the potential benefits of a Tier 4 option. Commenters representing both industry and environmental interests noted that the SEM option will encourage landfill owners and operators to implement methane reduction practices, such as the use of oxidative landfill covers, organic waste diversion, and interim gas control measures (horizontal gas collectors, connecting a leachate collection recovery system into a GCCS), noting that such practices can be implemented more quickly and more cost-effectively than a GCCS installed in accordance with the design plan requirements of the current Emission Guidelines. Commenters indicated that a SEM method reflects actual site-specific emissions data that account for gas generation differentials attributed to climate variations, waste acceptance rates, and cover soil materials that vary between landfills in different regions of the U.S. One commenter indicated that the use of SEM in determining the need to install a GCCS would reduce costs and energy consumption for landfills otherwise required to install controls, that would not generate a sufficient amount of gas to support a collection system but would remain below surface emission thresholds based on site-specific measurements. Another commenter added that a Tier 4 approach grants additional flexibility and a potential cost savings compared to the Tier 2 method, but cautioned that a surface monitoring methodology needs to be developed that is functional during windy conditions.
Commenters also considered how to implement a Tier 4 approach, including the hierarchy of the new tier relative to the existing tiers, procedures for conducting the SEM, the level of the appropriate exceedance, and what to do upon an exceedance. Several commenters suggested that Tier 4 could be employed at any point following a Tier 1 or Tier 2 test where the calculated NMOC emission rate is greater than the NMOC threshold for installing a GCCS. These same commenters suggested that landfill owners and operators have the option to perform Tier 4 SEM testing in the same areas and using the same methods currently established in 40 CFR part 60, subpart WWW. These commenters recommended that if an exceedance occurs during Tier 4 SEM testing, then landfill owners or operators should follow the same procedures and timelines for remediation and re-monitoring as outlined in subpart WWW. These commenters further suggested that if an exceedance cannot be remediated under the existing subpart WWW procedures, then the landfill would be required to prepare a GCCS design plan within 1 year of the initial exceedance and install a GCCS within the monitored area within 30 months of the initial exceedance. These commenters further suggested that if during the initial monitoring event methane surface emissions do not exceed 500 ppm over background, then the installation of a GCCS is not required and routine SEM should be performed until the landfill or area of the landfill is closed. One commenter requested that the EPA propose a surface concentration level of 200 ppm and indicated that this level provides empirical confirmation that the landfill is ready to install a GCCS.
After considering public comments and input from small entity outreach, the EPA is proposing Tier 4 SEM procedures for determining when a landfill must install a GCCS. Tier 4 allows landfill owners or operators to demonstrate that site-specific surface methane emissions are low. Under Tier 4, as proposed in this proposed rule, if the site-specific surface methane emissions are below 500 ppm for 4 consecutive quarters, then the requirement to install and operate a GCCS has not been triggered even in circumstances where emission estimates using Tiers 1, 2, and/or 3 are above the regulatory threshold. However, any quarterly surface emissions value over 500 ppm would trigger the requirement to install and begin operating a GCCS. If the landfill opts to use Tier 4 for its emission threshold determination and there is any measured concentration of methane of 500 parts per million or greater from the surface of the landfill, the owner or operator must install a GCCS, and it cannot go back to using Tiers 1, 2 or 3. The landfill owner or operator would be required to submit a design plan within 1 year of reporting the surface emissions value over 500 ppm to the implementing authority in an annual report and would be required to install and start up a GCCS within 30 months of reporting the surface emissions value over 500 ppm.
The SEM demonstration would be conducted using the SEM procedures described in sections IV.B and VI.A of this preamble. SEM would be conducted around the perimeter of the landfill and the required traverse every 30 meters for the entire landfill. Note that the EPA is requesting comment on enhanced surface monitoring, including the 30 meter traverse pattern, in section X.B of this preamble. The Tier 4 provisions can be utilized by any landfill that has exceeded the design capacity threshold. The Tier 4 provisions provide an incentive for a landfill owner or operator to keep surface emissions low as described later in this section.
Under this proposal, if a landfill exceeds the modeled NMOC emission
A landfill owner or operator may undertake Tier 4 SEM testing upon submitting an annual NMOC emission rate report that shows an NMOC emission rate greater than 34 Mg/yr using Tier 1, 2, or 3 procedures. If the landfill owner or operator chooses to undertake Tier 4 SEM instead of submitting a design plan and installing and operating a GCCS or estimating the NMOC emission rate using the next higher tier, then the landfill owner or operator would begin keeping records of all Tier 4 SEM readings and submit a “Tier 4 SEM report” as its next annual report. The report would include and identify the number of SEM readings above 500 ppm. If the report shows any SEM readings above 500 ppm methane, then the landfill would be required to submit a GCCS design plan within one year and install and begin operating a GCCS within 30 months. (The landfill could not take corrective action to correct the Tier 4 exceedance and could not estimate the annual NMOC emission rate using Tiers 1, 2, or 3.)
If the Tier 4 SEM report shows no SEM readings above 500 ppm for 4 consecutive quarters, then the landfill may continue Tier 4 monitoring at a reduced semi-annual frequency or return to Tier 1, 2, or 3. This approach allows owners or operators some flexibility to select the tier that is most applicable to their landfill, based on the point each landfill is in its lifecycle, and other site-specific factors. Note that a landfill can recalculate NMOC using Tiers 1, 2, or 3 only if it has 4 consecutive quarters with no SEM readings above 500 ppm.
The EPA selected a 500 ppm threshold for Tier 4 because it is consistent with the level the EPA determined to be appropriate to demonstrate that a GCCS is well-designed and well operated. In other words, when conducted properly, SEM is a good indicator of how well a GCCS is operating overall. For landfills without a GCCS (including those that may be using other LFG mitigation strategies), the level of 500 will demonstrate that site-specific surface methane emissions are as low as those allowed at a landfill with a well-operated and well-designed GCCS in place. See the docketed memorandum “Establishing a Site-Specific Emission Threshold Alternative for MSW Landfills, 2015.” Therefore the EPA believes this alternative site-specific concentration threshold will achieve the goal of minimizing methane emissions to the atmosphere. The EPA is aware that the surface emission threshold for installing a GCCS under the CA LMR is 200 ppm. However, the EPA also notes that CA LMR retains the 500 ppm level as an appropriate level for instantaneous SEM readings for areas already controlled by a GCCS. California ARB initially proposed a 200 ppm SEM threshold for both GCCS installation and for GCCS operation in its regulation, but finalized 500 ppm for GCCS operation because a lower threshold could cause an operator to overdraw the vacuum on the GCCS (to avoid a surface exceedance), which in turn could draw in too much oxygen and possibly cause fires. The EPA recognizes the concerns with setting the threshold too low, which may cause operators of voluntary GCCS to overdraw the vacuum on the GCCS, and has proposed a level of 500 ppm. The EPA requests comment on whether a level between 200 and 500 ppm is appropriate for the Tier 4 provisions, and whether setting the level below a specific point in this range poses fire or other safety concerns for operating a GCCS. The EPA also requests data that might support a different surface emissions threshold.
The EPA requests comments on whether landfill owners or operators should provide notification to EPA when conducting Tier 4 surface emissions monitoring. Such notification would be similar to the performance test notification required by 40 CFR 60.8(d), wherein the owner or operator of an affected facility provides the Administrator at least 30 days prior notice of any performance test to afford the Administrator the opportunity to have an observer present.
As noted earlier in this section, commenters representing both industry and environmental interests noted that the Tier 4 SEM option would encourage landfill owners or operators to implement alternative methane reduction practices, such as the use of oxidative landfill covers, interim gas control measures, and organic waste diversion. The EPA agrees. Such measures can directly affect surface emissions and when employed would help a landfill ensure that surface emissions are low, enabling a landfill to delay the regulatory requirement to install a GCCS without a significant negative impact on public health or the environment. Section V.A of this preamble discusses alternative methane reduction practices, such as the use of oxidative landfill covers, interim gas control measures, and organic waste diversion.
The EPA recognizes that many landfills or landfill areas are closed or
The EPA notes that many existing landfills in our dataset closed at various points since 1987, including landfills that closed as many as 18 years prior to this proposed action. In the ANPRM, the EPA presented the distribution of existing landfills by closure date (see Table 3, 79 FR 41792). These data showed that nearly 80 percent of the existing landfills with a design capacity of at least 2.5 million Mg and 2.5 million m
The EPA evaluated the costs and benefits of controlling emissions at a level between 34 Mg/yr and 40 Mg/yr at both open and closed landfills. Table 3 of section V.E of this preamble presents the number of landfills affected and the corresponding emission reductions and costs. The EPA also considered how closed landfills would be affected by this proposal. We are considering “closed” landfills to be those that closed after 1987 but on or before the date of this proposal.
At the baseline NMOC emission threshold of 50 Mg/yr, the EPA estimates that 29 of the 233 closed landfills with a design capacity of at least 2.5 million Mg and 2.5 million m
An NMOC emission rate threshold of 34 Mg/yr NMOC at closed landfills would achieve an additional 1,260 Mg NMOC and 5 million mtCO
See the docketed memorandum “Revised Cost and Emission Impacts Resulting from the Landfill EG Review (2015)” for additional detail on the impacts on closed landfills. In addition to these control costs, the EPA estimates that 160 closed landfills that are not controlling in 2025 would be required to estimate and report NMOC emissions under the proposed option because they have a design capacity of at least 2.5 million Mg and 2.5 million m
After closure, the gas flows at landfills decline and the ability to achieve additional reductions also declines. The EPA received input from SERs that many closed landfills supplement their flare with pilot (fossil) fuels in order to maintain flare operation despite declining gas quantities and quality. These SERs were concerned that a lower threshold at these closed landfills would extend the amount of pilot fuel necessary for flame stability. The EPA notes that closed landfills may have limited access to additional revenue because they are no longer collecting tipping fees and the cost for GCCS and regulatory compliance were not factored into their closure plans. Further, many SERs expressed concerns that many compliance costs are fixed cost items, regardless of the operating status of the landfill, such as permitting fees, drill rig mobilization fees, and others, as discussed in section V.D.1 of this preamble. Many SERs also expressed concerns about staffing limitations at closed landfills, who may have limited staff to oversee extended GCCS design, operations, maintenance, and compliance. For landfills that closed after August 27, 2015, the EPA understands that gas quality will remain a concern and it has provided an alternative set of GCCS removal criteria based on site-specific emissions, as discussed in section VIII.B of this preamble.
Commenters expressed concern about whether landfills that have closed and decommissioned their GCCS should be pulled back into control requirements if their emissions fall between the current 50 Mg/yr threshold and a more stringent NMOC emission threshold. These commenters recommended that the EPA exempt these landfills from more stringent control requirements. One commenter added that it would be costly to re-install or refurbish a previously shutdown system and noted that the system would likely operate for only a few more years before the landfill fell below the more stringent NMOC emission threshold. For example, the proposed reduction of the NMOC emission rate threshold to 34 Mg/yr NMOC could affect landfills that installed a GCCS to comply with the 50 Mg/yr NMOC emissions threshold in 40 CFR part 60, subpart WWW (or the state plans or federal plan implementing 40 CFR part 60, subpart Cc), but whose emissions are still above the EPA's proposed 34 Mg/yr NMOC threshold. These landfills could have declining gas flows, could be closed, or could have met the 40 CFR part 60, subpart WWW criteria for capping or removing the GCCS.
To address concerns about closed landfills, the EPA is proposing to create a subcategory of closed landfills, to which an NMOC emission rate threshold of 50 Mg/yr would apply, instead of an NMOC emission rate of 34 Mg/yr. The subcategory of closed landfills is proposed to be defined as a landfill that has submitted a closure report as specified in 40 CFR 60.38f(f) on or before August 27, 2015. As noted above, the emissions associated with the 65 closed landfills represents less than 7 percent of the total emission reductions achieved from all active and closed landfills expected to control emissions at a level of 34 Mg/yr NMOC in year 2025. The EPA believes this proposed subcategory for closed landfills alleviates concerns with lowering the threshold for closed
The EPA is requesting input on whether the proposed subcategory for closed landfills is the most appropriate method for controlling emissions and addressing concerns with closed landfills, or whether the EPA should consider exempting closed landfills from the proposed subpart Cf entirely. The EPA is also requesting comments on whether additional provisions should be considered for closed landfills when establishing the revised Emission Guidelines, including whether the closed landfill subcategory should be expanded to include landfills that closed within 13 months after publication of the Emission Guidelines in the
Several commenters requested that the EPA reconsider the 15-year criteria for capping or removing a GCCS and one commenter stated that the 15-year period should be longer, rather than shorter. Commenters supported the use of Tier 4 SEM procedures to help determine the removal or decommissioning of existing GCCS. Commenters supported the use of SEM to allow the flexibility to confirm when a closed landfill or closed area of a landfill no longer producing gas in significant quantities can remove or decommission all or a portion of the GCCS. Several of these commenters referenced a rationale similar to the one they provided for supporting the use of Tier 4 SEM for determining GCCS installation as discussed in section VII.A of this preamble. Several commenters requested that the EPA provide a “step-down” procedure for scaling down GCCS operations in non-producing areas and allowing a GCCS to be removed from rule applicability.
The EPA is proposing two sets of criteria for capping and removing the GCCS. The first set of criteria is similar to the criteria in subpart Cc, but has been adjusted to reflect the new NMOC emission threshold proposed in this proposal: (1) The landfill is closed, (2) the GCCS has been in operation for 15 years, and (3) three successive tests for NMOC emissions are below the proposed NMOC emission threshold of 34 Mg/yr for open landfills and50 Mg/yr NMOC for closed landfills. The EPA is also proposing an alternative set of criteria for capping or removing the GCCS that employs a SEM demonstration: (1) The landfill, or an area of an active landfill, is closed, (2) the GCCS has operated for at least 15 years or the landfill owner or operator can demonstrate that the GCCS will be unable to operate for 15 years due to declining gas flows, and (3) the owner or operator demonstrates for 4 consecutive quarters that there are no surface emissions of 500 ppm or greater from the landfill or closed area. The EPA selected a level of 500 ppm to be consistent with the operational standard for operating a GCCS. The operational standard is the surface emissions level that cannot be exceeded once a GCCS has been installed.
The EPA proposes the use of SEM procedures in section VI.A of this preamble for determining when to decommission wells and for when the landfill can cap or remove a GCCS. If a landfill owner or operator can demonstrate that surface emissions in the closed area of an open landfill or a closed landfill are below 500 ppm for 4 consecutive quarters, then they would be able to stop collecting gas from that area or the landfill as a whole. After 4 consecutive quarters of no exceedances, the landfill continues to monitor the closed area annually for surface emission exceedances of 500 ppm or greater. If exceedances are found, the landfill must restart the GCCS in the closed area and the GCCS would be required to operate according to proposed 40 CFR part 60, subpart Cf.
As discussed in section VII.A of this preamble, surface emissions monitoring more closely reflects the site's actual emissions and accounts for differences in gas generation due to waste composition and local conditions. As discussed in section VII.A of this preamble, sites will have the incentive to employ various technologies or practices to minimize surface emissions, thus giving the owner or operator flexibility at both the installation and removal stages of LFG collection and control. With these rule provisions, the EPA can ensure environmental protection is demonstrated through low surface emissions and landfill owners or operators will have the flexibility to cap or remove the GCCS based on site-specific surface emission readings.
Commenters have identified the difficulty of operating a GCCS in “non-producing” areas and meeting the wellhead operational standards for the GCCS. They have also contended that the corrective action—expanding the GCCS, is counter to a “well-operated” GCCS. Several commenters requested that the EPA provide flexibility to meet the wellhead and other requirements in “non-producing” areas. Commenters generally consider a “non-producing” area as one with declining LFG generation and gas flow, which in turn make it difficult to continuously meet the operational standards for a GCCS. One commenter stated that when landfill gas production decreases significantly, even small amounts of vacuum can draw air into the waste mass causing exceedances of the wellhead oxygen parameter. The commenter added that the landfill owner or operator may address the oxygen exceedance by reducing the vacuum to a very low level, but then may not be able to maintain negative pressure. Another commenter stated that LFG wells in old waste can be very sensitive to vacuum adjustments, easily exceeding the 5 percent oxygen standard not due to excessive air infiltration, but rather due to low LFG volume. Other commenters noted that the difficulty of meeting the wellhead oxygen/nitrogen operational standards could be exacerbated if the EPA were to reduce the NMOC emissions threshold below 50 Mg/yr.
As discussed in section VI.B of this preamble, the EPA proposes to remove the requirement to meet wellhead operating standards for temperature and nitrogen/oxygen. Removing these two standards will not only promote earlier and more robust collection of LFG as discussed in section VI.B of this preamble, but will also give owners or operators flexibility to operate the GCCS in non-producing or closed areas without the risk of exceeding the oxygen/nitrogen operating standards. Removing the requirement to meet the oxygen/nitrogen operating standards and the need for corrective action, including expanding the GCCS, will reduce the burden on both the landfill owner or operator and the implementing authority. As discussed in section VIII.B of this preamble, the EPA is also providing flexibility for temporary decommissioning of wells in closed landfills or closed areas of active landfills to provide flexibility for meeting negative pressure in areas that can demonstrate low surface emissions.
The EPA is proposing a definition of treated landfill gas and treatment system. A
The approach is consistent with public comments received on previous landfills documents (67 FR 36475, May 23, 2002; 71 FR 53271, September 8, 2006; 79 FR 41796, July 17, 2014; 79 FR 41772, July 17, 2014), as well as input from participants in small entity outreach, who stated that the extent of filtration, de-watering, and compression can be site- and equipment-dependent, and that different sites require different levels of gas treatment to protect the combustion devices that use treated LFG as a fuel and ensure good combustion.
Commenters on the proposed NSPS (79 FR 41796) and ANPRM (79 FR 41772) supported the expanded use of treated LFG. Commenters including state/local agencies, a large landfill owner or operator, and an industry trade association supported the expanded beneficial use of LFG to include uses beyond subsequent sale or use and agreed that a broader definition is appropriate. No commenters opposed the expanded use.
Many commenters on the July 17, 2014 proposed NSPS (79 FR 41796) and ANPRM (79 FR 41772) opposed a definition of LFG treatment based on specific numerical values for filtration and de-watering. Numerous commenters disagreed with a requirement to meet specific absolute filtration and dew point suppression values and contended that a “one-size-fits-all” approach was not appropriate, and would not reduce emissions. One commenter specifically noted the impact that the costs of these requirements would have on small entities.
Commenters estimated costs to comply with the dew point reduction. Based on experience, commenters estimated that chillers alone would cost $500,000 each. Commenters estimated that instrumentation, monitoring, and controls would cost an additional $150,000 per chiller, plus up to $60,000 for annual maintenance, monitoring, and operation. These commenters also expressed concerns about the timeframe for installing chillers. Plus, many commenters also expressed concern that the numerical requirements would be detrimental to existing and potential beneficial use projects, including potentially shutting down existing beneficial use projects and preventing future ones.
On the other hand, many commenters supported the more flexible definition of treatment system that allows the level of treatment to be tailored to the type and design of the specific project equipment. Commenters pointed out that owners and operators of combustion equipment are already motivated to treat landfill gas to manufacturer specifications to protect equipment and maintain warranties. Commenters added that compliance with a site-specific definition of treatment can be tracked using a preventative maintenance plan.
The EPA recognizes that the landfill industry continues to develop new LFG beneficial use projects and the EPA continues to support the recovery and use of LFG as an energy source. Thus, the EPA is proposing a simplified definition of treatment as filtering, de-watering, and compressing landfill gas, but is retaining as alternative a definition of LFG treatment based on specific numerical values for filtration and de-watering.
The simplified definition of treatment, combined with site- and equipment-specific monitoring, is expected to provide compliance flexibility, ensure environmental protection, and promote the beneficial use of LFG. The proposed definition would allow the level of filtration, dewatering, and compression to be tailored to the type and design of the specific equipment in which the LFG is used. Owners or operators would need to identify monitoring parameters, be able to demonstrate that such parameters effectively monitor filtration, de-watering or compression system performance necessary for the end use of the treated LFG and keep records to demonstrate that the parameters are being met.
Owners or operators would also need to develop a site-specific treatment system monitoring plan that would not only accommodate site-specific and end-use specific treatment requirements for different energy recovery technologies, but would also ensure environmental protection. A well-operated system with a level of treatment specific to the site and end-use equipment would prevent equipment disruptions and limit emissions resulting during shutdowns or malfunctions. A treatment approach that can be tailored to the end use of the gas would also promote wider use of LFG energy recovery, by limiting the compliance burden for those landfills opting to include an energy recovery component. Landfill gas energy recovery protects the environment by not only controlling LFG and its components, but also by offsetting conventional sources of energy with a renewable resource for heating, electricity, vehicle fuel, or other innovative end uses. The EPA also notes that landfills complying with a treatment compliance option are also subject to the surface emissions monitoring requirements discussed in section VI.A of this preamble to ensure that the GCCS is well operated and surface emissions are minimized. Preparing the monitoring plan would document procedures that landfills are likely already following to ensure that the LFG has been adequately treated for its intended use and provide verifiable records of proper operation to the EPA or other implementing authorities.
The plan would be required to include monitoring parameters addressing all three elements of treatment (filtration, de-watering, and compression) to ensure the treatment system is operating properly for the intended end use of the treated LFG. The plan would be required to include monitoring methods, frequencies, and operating ranges for each monitored operating parameter based on manufacturer's recommendations or engineering analysis for the intended end use of the treated LFG. Documentation of the monitoring methods and ranges, along with justification for their use, would need to be included in the site-specific monitoring plan. In the plan, the owner or operator would also need to identify who is responsible (by job title) for data collection, explain the processes and methods used to collect the necessary data, and describe the procedures and methods that are used for quality assurance, maintenance, and repair of all continuous monitoring systems.
The owner or operator would be required to revise the monitoring plan to reflect changes in processes, monitoring instrumentation, and quality assurance procedures; or to improve procedures for the maintenance and repair of monitoring systems to reduce the frequency of monitoring equipment downtime.
In its 2008 decision in
The part 60 general provisions, which define startup, shutdown, and malfunction, were written for typical industrial or manufacturing sources and associated processes. Many of these sources and processes may, at times, be shut down entirely for clean-out, maintenance, or repairs, and then restarted. Applying the standards at all times, including periods of startup and shutdown, is intended to minimize excess emissions when the source or process ceases operation or commences operation, or during malfunctions. Landfill emissions, however, are produced by a continuous biological process that cannot be stopped or restarted. For landfills, the primary SSM concern is with malfunction of the landfill GCCS and associated monitoring equipment, not with the startup or shutdown of the entire source. Thus, SSM provisions in the 40 CFR part 60, subpart Cf focus primarily on malfunction of the gas collection system, gas control system, and gas treatment system, which is part of the gas control system.
Further, accounting for malfunctions in setting emission standards would be difficult, if not impossible, given the myriad different types of malfunctions that can occur across all sources in the category and given the difficulties associated with predicting or accounting for the frequency, degree, and duration of various malfunctions that might occur. As such, the performance of units that are malfunctioning is not “reasonably” foreseeable. See,
In the event that a source fails to comply with the applicable CAA section 111 standards as a result of a malfunction event, the EPA would determine an appropriate response based on, among other things, the good faith efforts of the source to minimize emissions during malfunction periods, including preventative and corrective actions, as well as root cause analyses to ascertain and rectify excess emissions. The EPA would also consider whether the source's failure to comply with the CAA section 111 standard was, in fact, sudden, infrequent, not reasonably preventable and was not instead caused in part by poor maintenance or careless operation (40 CFR 60.2 (definition of malfunction)).
If the EPA determines in a particular case that an enforcement action against a source for violation of an emission standard is warranted, the source can
In summary, the EPA interpretation of the CAA and, in particular, CAA section 111 is reasonable and encourages practices that will avoid malfunctions. Administrative and judicial procedures for addressing exceedances of the standards fully recognize that violations may occur despite good faith efforts to comply and can accommodate those situations.
In several prior rules, the EPA had included an affirmative defense to civil penalties for violations caused by malfunctions in an effort to create a system that incorporates some flexibility, recognizing that there is a tension, inherent in many types of air regulation, to ensure adequate compliance while simultaneously recognizing that despite the most diligent of efforts, emission standards may be violated under circumstances entirely beyond the control of the source. Although the EPA recognized that its case-by-case enforcement discretion provides sufficient flexibility in these circumstances, it included the affirmative defense to provide a more formalized approach and more regulatory clarity. See
To prevent free venting of landfill gas to the atmosphere during control device malfunctions, we propose to include a requirement in subpart Cf (40 CFR 60.34f(e)) that states that in the event the collection or control system is not operating, the gas mover system must be shut down and all valves in the collection and control system contributing to venting of gas to the atmosphere must be closed within 1 hour. The EPA proposes to use the term “not operating,” which includes periods when the gas collection or control system is not operating for whatever reason, including when the gas collection or control system is inoperable. The EPA requests comment on the technical feasibility of this approach as well as alternate ways to prevent free venting of landfill gas to the atmosphere during control device malfunctions.
Shutting down the gas mover equipment and all valves contributing to venting of gas to the atmosphere minimizes emissions from the landfill while the control system is not operating and is being repaired. Compliance with proposed 40 CFR 60.34f(e) does not constitute compliance with the applicable standards in proposed 40 CFR 60.36f; however, as a practical matter it is unlikely that there would be a violation since no gas would be flowing to the control device. Compliance with proposed 40 CFR 60.34f(e) is necessary to demonstrate compliance with the general duty to minimize emissions in 40 CFR 60.11(d) during control or collection system malfunctions.
Under proposed 40 CFR part 60, subpart Cf, landfill owners or operators must keep records of combustion temperature, bypass flow, and periods when the flare flame or the flare pilot flame is out. However, without additional provisions, the EPA would have no way to gauge the severity of an emissions exceedance that may occur when these operating parameters are not being met or when the control device is not operating. Therefore, the EPA is proposing to include provisions for landfill owners or operators to estimate NMOC emissions when the control device or collection system is not operating. The landfill owners or operators may use whatever information is available to estimate NMOC emissions during the period, including but not limited to, landfill gas flow to or bypass of the control device, the concentration of NMOC (from the most recent performance test or from AP-42), and the amount of time the control
As discussed above, malfunctions are by definition sudden, infrequent and not reasonably preventable failures of emissions control, process or monitoring equipment. Further, there are myriad different types of malfunctions that can occur and there are significant difficulties associated with predicting or accounting for the frequency, degree, and duration of various malfunctions that might occur. As a result, the EPA believes that it is generally not technically feasible to establish an alternative emission standard that would apply during periods of malfunction. The EPA also believes that it would be difficult to defend an alternative standard that does not achieve a level of emission reduction comparable to that required by the standard that applies during periods of normal operation in circumstances where there are steps that an owner or operator could take to achieve such reductions such as shutting down the process or having a second control device. In the immediate case, by shutting down the flow to the flare or other control device a source is unlikely to be in violation of the 98 percent emission reduction requirement since there will be no gas flowing to the control device. We are, however, interested in comment on whether there are alternative ways in which the emission limit could be complied with when the control device malfunctions.
We propose to include definitions of “household waste” and “segregated yard waste” in proposed 40 CFR part 60, subpart Cf to clarify our intent regarding the applicability of proposed subpart Cf to landfills that do not accept household waste, but accept segregated yard waste. We also proposed to exclude construction and demolition waste from the definition of household waste. We intend for subpart Cf to apply to MSW landfills that accept general household waste (including garbage, trash, sanitary waste), as indicated in the definitions. We do not intend the landfills rules to apply to landfills that accept only segregated yard waste or a combination of segregated yard waste and non-household waste such as construction and demolition waste.
In the ANPRM for the Emission Guidelines (79 FR 41772), the EPA requested input on how non-producing areas of the landfill,
Commenters expressed concern with the requirement for closed areas to be physically separated in order to be excluded from GCCS requirements, noting that many closed areas of active landfills are non-producing but remain physically connected to other areas of the landfill.
To help address the difficulty of controlling landfill gas in low-producing areas, the EPA is proposing an alternative set of criteria for capping or removing the GCCS that employs a SEM demonstration: (1) The landfill is closed or an area of an active landfill is closed, (2) the GCCS has operated for at least 15 years or the landfill owner or operator can demonstrate that the GCCS will be unable to operate for 15 years due to declining gas flows, and (3) the landfill or closed area demonstrates for 4 consecutive quarters that there are no surface emissions of 500 ppm or greater. The EPA is also requesting comment on whether owners or operators of physically separated, closed areas of landfills may model NMOC emission rates, or may determine the flow rate of landfill gas using actual measurements, to determine NMOC emissions in order to identify areas that can be excluded from gas collection. The EPA considers areas to be physically separated if they have separate liners and gas cannot migrate between the separate areas.
To further address non-producing areas, proposed 40 CFR part 60, subpart Cf contains procedures for excluding areas from gas collection and control. Owners or operators of landfills with physically separated, closed areas may demonstrate that the quantity of NMOC emissions from the area is less than 1 percent of the total NMOC emissions from the entire landfill, and thus exclude the area from control. Under proposed 40 CFR part 60, subpart Cf, owners or operators of landfills with physically separated, closed areas may model NMOC emission rates, or may determine the flow rate of landfill gas using actual measurements, to determine NMOC emissions. Using actual flow measurements would yield a more precise measurement of NMOC emissions for purposes of demonstrating the closed area represents less than 1 percent of the landfills total NMOC emissions.
Because both of these topics rely on defining a closed area of a landfill, the EPA requests comment on how to define closed areas of open landfills.
The proposed 40 CFR part 60, subpart Cf collection and control requirements are intended to ensure that landfills maintain a tight cover that minimizes any emissions of landfill gas through the surface. The surface emissions monitoring procedures in proposed 40 CFR part 60, subpart Cf are consistent with 40 CFR part 60, subpart WWW and require quarterly surface emissions monitoring to demonstrate that the cover and gas collection system are working properly. However, we are also considering and requesting additional public input on a potential alternative approach to surface emissions monitoring.
The alternative surface monitoring approach includes changing the walking pattern that traverses the landfill from 30 meters (98 ft) to 25 ft and adding a methane concentration limit of 25 ppm as determined by integrated surface emissions monitoring. This would be in addition to the 500 ppm emission concentration as determined by instantaneous surface emissions monitoring. Integrated surface emissions monitoring provides an average surface emission concentration across a specified area. For integrated surface emissions monitoring, the specified area would be individually identified 50,000 square ft grids. A tighter walking pattern and the addition of an integrated methane concentration limit would more thoroughly ensure that the collection system is being operated properly, that the landfill cover and cover material are adequate, and that methane emissions from the landfill surface are minimized in all types of climates. As part of these potential changes, the EPA is also considering not allowing surface monitoring when the average wind speed exceeds 5 miles per hour (mph) or the instantaneous wind speed exceeds 10 mph because air movement can affect whether the
Many commenters supported the enhanced surface monitoring provisions for detecting surface emissions. A state agency supported reducing the traverse pattern to 25 feet, stating that the tighter traverse pattern would increase the chance of detecting exceedances. An environmental organization supported all elements of the enhanced surface monitoring and contended that the current monitoring at 30 meter intervals leaves most areas of the landfill unmonitored. Both these commenters suggested that the walking pattern be varied each quarter (
Many commenters opposed the enhanced surface monitoring provisions. Commenters that opposed the enhanced surface monitoring provisions primarily cited the additional costs and contended that the additional expense was not warranted because of limited environmental benefits. Two commenters commissioned a study to compare the level of effort and monitoring results of the CA LMR to the SEM requirements under the current NSPS (40 CFR part 60, subpart WWW). The CA LMR utilizes a 25 ft traverse pattern, an instantaneous as well as integrated reading, and prevents sampling during windy conditions (greater than 5 mph average and greater than 10 mph instantaneous).
The study examined monitoring results for eight quarters of NSPS surface monitoring at 42 California landfills, encompassing 27,140 acres. Those results were compared to CA LMR surface monitoring for 10 quarters at 72 California landfills, including the 42 landfills conducting NSPS surface monitoring, encompassing a total of 57,151 acres. Among other observations, the study concludes that although the CA LMR surface emission monitoring requirements detected 2.1 percent more exceedances than NSPS surface emission monitoring requirements, detecting these additional exceedances is not cost effective. The study also concluded that under the NSPS monitoring, only one landfill was required to expand its GCCS, while under the CA LMR monitoring, only three landfills were required to expand the GCCS. The two commenters that commissioned the study contended that the additional cost to conduct enhanced surface monitoring, estimated by the EPA to be seven times more expensive than NSPS monitoring, was an extraordinary amount of money to spend detecting exceedances at merely an additional 2.8 percent of acres monitored, while increasing gas collection at only one landfill.
The EPA examined the data supporting the study as provided by one of the commenters. The data allowed for direct comparison of exceedance data from 29 landfills, although for different time periods. The study and supporting data provide evidence of greater exceedances under the California approach than the current approach. However, the EPA was unable to determine the magnitude of emission reductions that might result from the greater exceedances under the California approach. See the docketed memorandum entitled “Analysis of Surface Exceedances from California Landfills under the New Source Performance Standards and the California Landfill Methane Rule.”
Many commenters, including many state agencies, opposed limiting surface monitoring during windy conditions, stating that the wind restrictions would be a significant inhibitor to completing the required monitoring in many regions of the country due to typical windy conditions. Commenters also stated that it would be difficult to schedule and reschedule dedicated sampling crews and conditions could change quickly during sampling events, causing crews to stop monitoring.
For proposed 40 CFR part 60, subpart Cf, the EPA estimated the costs associated with both the proposed subpart Cf surface monitoring requirements (which are the same as the surface monitoring requirements in 40 CFR part 60, subpart WWW) and potential changes to the surface monitoring provisions under the proposed 2.5/34 option and the proposed 2.5/40 option and applied them to the set of existing landfills that would be subject to control requirements under the respective option. To determine the costs, the EPA used the following assumptions: Most landfills will hire a contractor to conduct the quarterly monitoring. The landfill will incur labor costs based on the time it takes to walk the traverse (hours per acre), the size of the landfill (acres), and a labor rate (dollars per hour). The landfill will also incur an equipment rental rate (dollars per hour) as well as a flat fee for purchasing calibration gases and hydrogen to fuel the equipment. Equipment rental rates are dollar per day/week/month, depending on the size of the landfill and time to traverse the acreage during each quarterly period. See the docketed memo, “Updated Methodology for Estimating Testing and Monitoring Costs for the MSW Landfill Regulations. 2015,” which contains the details for determining the costs that a landfill would incur to conduct enhanced surface monitoring.
Using the techniques discussed in section V.B of this preamble, the EPA estimated the number of landfills that are expected to install controls under the baseline, as well as the proposed option 2.5/34 and option 2.5/40. Then, the EPA applied surface monitoring costs to the respective set of landfills because landfills that must install controls must also conduct surface monitoring. Table 4 of this preamble compares the enhanced surface monitoring costs that would be incurred for new landfills under the baseline and proposed option 2.5/34 and proposed option 2.5/40.
Several factors contribute to the cost of enhanced surface monitoring. Monitoring along a traverse with a 25 ft. interval would increase monitoring time, and thus the labor costs, compared to monitoring along a 30 meter (98 ft.) interval. Monitoring along the tighter traverse pattern would take approximately 4 times as long, because the distance is approximately 4 times greater. For a landfill to conduct the integrated surface emissions monitoring, the EPA assumed the landfill would rent a handheld portable vapor analyzer with a data logger. The data logger is necessary to obtain an integrated reading over a single 50,000 square foot grid. However, the EPA does not expect that requiring an integrated methane concentration would add significant cost because landfills could use the same instrument that they currently use for the instantaneous readings and these instruments can be programmed to provide an integrated value as well as an instantaneous value.
The EPA recognizes that these provisions could reduce surface emissions and that these emissions reductions are difficult to quantify. The EPA also understands that there are potential implementation concerns with these enhanced procedures. Surface monitoring is a labor intensive process and tightening the grid pattern would increase costs. Of the 574 landfills expected to be controlling in 2025 under the baseline, it would take these landfills over 42 hours, on average, to complete each quarterly traverse pattern. Tightening the traverse pattern to 25 ft instead of 30 meters would require over 165 hours per quarter, or nearly 500 additional hours per year, per landfill, compared to the current 30-meter traverse pattern.
At this time, the EPA is not proposing surface monitoring provisions that differ from those outlined in 40 CFR part 60, subpart WWW, but we are soliciting comment on the various elements of enhanced surface emissions monitoring (the width of the traverse pattern, offsetting the walking pattern each quarter (
In the ANPRM (79 FR 41784), we solicited input on separate thresholds for wet landfills and how wet landfills might be defined. Among other concerns, we received feedback from commenters expressing concern on potential overlap between wet landfills handled under the Emission Guidelines and bioreactor landfills handled under 40 CFR part 63, subpart AAAA (National Emission Standards for Hazardous Air Pollutants: Municipal Solid Waste Landfills). A landfill is defined as a bioreactor under 40 CFR part 63, subpart AAAA if it has added liquids other than leachate into the waste mass in a controlled fashion;
Collectively, reductions from these 377 wet landfills constitute approximately 50 percent of the incremental reductions achieved by the proposed option 2.5/34. Nearly all of these incremental reductions are coming from the 343 landfills that are located in areas receiving 40 inches of precipitation or more. Based on this analysis, the NMOC threshold of34 Mg/yr in this proposal achieves significant reduction in emissions from wet landfills.
The EPA conducted a preliminary analysis to determine the additional reductions that could be achieved if the initial lag time was shortened by 1 year and the expansion lag time was shortened by 2 years and applied to open wet landfills in addition to the lower NMOC emission threshold of 34 Mg/yr. The results of this analysis show
It is important to note that the impacts of the options in Table 3 as well as this preliminary analysis of wet landfills were conducted using a k value of 0.04 for any landfill that is located in an area with at least 25 inches of rainfall, consistent with the analysis discussed at 79 FR 41805. This modeling parameter was used for all but nine of the 377 wet landfills discussed above. Those nine landfills, which are either RD&D landfills or reported significant leachate recirculation to subpart HH of the GHGRP were modeled using a k value of 0.02 because they were located in arid areas.
The results of the impacts analyses presented in Table 3 of this preamble and above could differ significantly if alternative modeling parameters (k and/or L
Given the additional emission reductions that could be achieved from shortening the lag times at wet landfills and in consideration of the President's Methane Strategy, the EPA is soliciting input on whether the wet landfills not subject to the requirements in 40 CFR part 63, subpart AAAA should be subject to different schedules for installing and expanding their GCCS under the Emission Guidelines. Additionally, the EPA requests comment on how these wet landfills that are not bioreactors (as defined in subpart AAAA) might be defined. Finally, recognizing the wide range of k values used to model emissions at wet landfills (0.057 to 0.3), the EPA requests comment and data to support revising the k value used for assessing the impacts on wet landfills, as well as the k value landfills should use in Tier 1 and Tier 2 emission threshold determinations. The EPA also requests comment on whether revisions to the k value for wet landfills would require changes to the Lo modeling parameter for wet landfills.
Based on comments received and discussed in section VI.B of this preamble, as well as the proposal to eliminate the operating standards for oxygen/nitrogen and temperature, the EPA is requesting input on whether it should add a requirement to monitor wellhead flowrate to help ensure a well-operated GCCS. Monitoring wellhead flow rate would allow the landfill owner or operator to detect low gas flow and whether a well is waterlogged, clogged, or pinched. The EPA is also requesting comment on any other wellhead monitoring parameters that would help ensure a well-operated GCCS.
In the ANPRM for existing landfills (79 FR 41784, July 17, 2014), the EPA solicited input on the possibility of establishing a third-party design plan certification program and provided examples of several rules and programs with third-party verification components. The third-party program would supplement or replace the current approach of requiring EPA or state review and approval of site-specific design plans and plan revisions with a program whereby independent third parties would review the design plans, determine whether they conform to applicable regulatory criteria, and report their findings to the approved state programs or the EPA (for states without approved programs). The process of approving site-specific design plans and plan revisions can be extremely resource-intensive for regulators and regulated entities alike. The EPA believes modifying the regulations to provide for the review and approval of the plans by competent and independent third parties could reduce these burdens. Such an independent program would need to be designed to ensure that, among other things, the third parties are competent, accurate, independent, and appropriately accredited. The program would also need to ensure that the reviews are thorough, independent, and conducted pursuant to clear and objective design plan review criteria. Finally, the program would need to ensure that the system is transparent, including requiring appropriate public disclosures, and that there is regular and effective oversight of the third-party system. Some criteria for auditor competence, independence, reporting, and oversight requirements provisions might include the following:
• Engaging a third-party inspection team (team) and submitting the members' resumes and qualifications to EPA;
• Requiring the team to have at least one person with landfill industry expertise acceptable to the EPA, one expert in environmental compliance auditing, and one expert in chemical process safety management;
• Restricting team members to those who have not previously performed work for the respondents;
• Restricting team members from working for the respondents or any of the respondents' officers for 5 years after completion of inspections;
• After giving the respondents notice of the first upcoming inspection, restricting the team from
• Unannounced follow-up inspections with no notice to respondents but advance notice to the EPA;
• Restricting respondents from having control over the timing of any of the follow-up inspections;
• Having the EPA or the delegated authority retain the right to accompany the team on any inspection;
• Within 15 days of each inspection, requiring the team to simultaneously submit to the EPA and the respondents an inspection report, photographs, and digital video of the inspection;
• Denying the opportunity to review any draft or final inspection report before its submittal.
The EPA developed the above provisions based on the theoretical and empirical research for best practices for independent third-party audits.
Commenters on the ANPRM generally did not support a third-party design plan certification program and cited several reasons. Commenters noted that the ANPRM (79 FR 41772) discussion of the program was overly general and that the EPA did not adequately describe the possible design features. One commenter expressed concerns that the examples of third-party certification presented in the ANPRM are neither comparable nor relevant to the review of MSW landfill GCCS design plans. One commenter acknowledged that a third-party reviewer system could reduce the burden and backlog experienced by reviewing agencies, but expressed concern that the costs of verification would be significant. Another commenter indicated the EPA did not present any economic and implementation impacts concerning such a program in the ANPRM and requested that EPA provide more details. Commenters also expressed concern about finding consultants that would be free of conflicts of interest given the consolidated nature of the MSW landfill industry. One commenter noted that cost and potential conflicts of interest were cited as reasons that the EPA did not adopt a third-party certification program for the GHGRP. Another commenter agreed that there was the potential for conflicts of interest and stated that design plan review is an essential government oversight and should not be delegated. Commenters also urged the EPA to thoroughly review the many issues that could arise with a third-party certification program and urged the EPA to take further notice and comment before promulgating such a program.
Several commenters on the ANPRM (79 FR 41772) solicited additional details on components of a proposed third-party certification program, and the EPA is providing further details in this proposal. In this document, the EPA is also seeking additional input on the possibility of establishing a third-party design certification program. This preamble discussion provides notice of the key features the EPA is considering in such a program to ensure the integrity of such a program, including the use of effective auditors and audits. See the docketed memorandum “Using Third-Party Audits to Improve Compliance” for additional specificity regarding such third-party design features with supporting studies, articles, and reports.
Third-party compliance verification occurs when an independent third party verifies to a regulator that a regulated entity is meeting or conforming to one or more compliance obligations (in the literature and other regulations, the terms “certifier,” “auditor,” or “inspector” are also used to describe such verifiers). Independent third-party programs are distinct from programs whereby regulated sources employ contractors or consultants, even if they are separate legal entities from the regulated facilities and are highly qualified. When contractors or consultants report to facilities directly, have other non-audit business or relationships with the facilities, and/or the facilities are able to control or influence the audit reports' form and/or content, this is not independent third-party verification but rather enhanced self-auditing.
Based on careful review of the literature,
a. A requirement that the auditing (verifying) firm, including any corporate parent and/or subsidiaries and the actual persons responsible for the audit, neither have had any prior business or family relationship with the firm being audited in the past five years, nor have worked on the development or implementation of the project/process subject to the audit.
b. A requirement that the auditing firm (including its corporate parent and/or subsidiaries, if any) is prohibited from engaging in any business transactions with the firm it is auditing for at least five years after the audit is completed.
c. A requirement that the verifying entity and the specific auditors hold appropriate professional and educational credentials issued by either the government entity that would otherwise review the plan or an independent professional organization (accreditation board) neither funded nor associated with the regulated sector.
d. A requirement that the auditing firm share all drafts and the final version of its audits with the government entity before, or at the same time, as it shares them with the regulated entity.
e. A requirement that appropriate auditing standards and protocols be spelled out, including, if possible, by reference to identified standards established by outside entities,
f. A requirement that audit reports, including names of key persons involved in the audits, be made accessible to the public subject to protecting confidential business information (CBI) and national security information
g. Requirements to ensure that the verifying firms operate with integrity, competence, and independence and that the regulator audit,
The EPA is requesting comments regarding the appropriate professional and educational credentials
The EPA is also considering defining more specifically what it means for an auditor to be independent,
The EPA is also considering allowing a person at the facility who is a registered professional engineer to conduct the audit at the facility,
As another alternative approach, the EPA could require auditors to have accreditation by a recognized accrediting body. Several of the examples that have already been provided of existing or proposed federal or state independent third-party auditing programs in rules use this approach. The EPA thus seeks comment on whether third-party auditors should be required to receive accreditation by a recognized accrediting body. The EPA also seeks comment on the standards such accrediting bodies should be required to meet,
There are advantages to third-party auditing, particularly with strong auditor competence and independence criteria. According to the Center for Chemical Process Safety (CCPS), “Third-party auditors (typically, consulting companies who can provide experienced auditors) potentially provide the highest degree of objectivity.”
All independent third-party compliance verification programs establish criteria and standards for auditor competence. Typically, such criteria and standards combine specified minimum levels of education, knowledge, experience, and training. Auditors should be knowledgeable and experienced with the facility type and processes being audited. The applicable recognized and generally accepted good engineering practices, trained or certified in proper third-party auditing techniques, and licensed professional engineers should be employed where appropriate. The EPA seeks comment on whether these criteria are appropriate and sufficient to ensure that auditors are competent to perform high-quality auditing.
It is EPA policy that both the government and the public have appropriate access to information about regulated entities and their compliance status. This includes relevant information on the operation of any independent third-party programs. The EPA seeks comment on what information associated with such a program for landfills should be publicly disclosed and how to disclose it.
Pursuant to EPA's Policy Statement on E-Reporting in EPA Regulations (September 30, 2013), “[t]he Policy of the [EPA] is to [b]egin the regulatory development process with the assumption that all reporting will be electronic, unless there is a compelling reason to use paper reporting. Consistent with that policy, the EPA is requesting comment on requiring independent third-party auditors to provide their audit reports and associated certification statements (see discussion below) to EPA electronically and seeks comment on how to best design the e-reporting system to facilitate its use by the regulated facilities and third-party auditors.
EPA's experience shows that requiring a responsible corporate or third-party official to attest to self-monitoring, reporting, and third-party auditing can help ensure that appropriate officials are personally familiar with the reported information and reminds them of the penalties associated with knowingly submitting false information. The EPA intends to require such language for any third-party audit reports under these emission guidelines and requests comment on its wording. The EPA also requests comment on whether the Agency should, for this rule, require regulated facilities and/or third-party auditors to
Third-party audits or other forms of compliance verification are also required by a variety of final or proposed EPA programs to promote compliance with regulatory standards. Examples of proposed or final federal environmental regulatory programs with built-in third-party verification include the following rules and rulemakings:
• EPA CAA Renewable Fuel Standard (RFS) program: The RFS regulations include requirements for obligated parties to: (1) Meet annual attest engagement requirements using independent certified public accountants (the purpose of attest engagements is to provide regulated parties an independent review of their compliance with both the fuels requirements themselves as well as the regulated party's internal systems to monitor and document compliance); (2) submit independent third-party engineering reviews to the EPA before generating Renewable Identification Numbers.
• EPA CAA wood stoves rule: Residential wood heaters (which include stoves) contribute significantly to particulate air pollution. Wood stove model lines that are in compliance with the wood stoves rule are referred to as EPA-certified wood stoves. The EPA's certification process requires manufacturers to verify that each of their wood stove model lines meet a specific particulate emission limit by undergoing emission testing at an EPA-accredited laboratory.
In the proposed NSPS (79 FR 41796), as well as 40 CFR 60.37f(a)(2) of the proposed Emission Guidelines, landfill owners or operators must use Method 3A or Method 3C when monitoring the oxygen and nitrogen levels at the wellhead, unless an alternative test method is established. Several commenters on the proposed NSPS requested that the EPA specify that portable gas composition analyzers are an acceptable alternative to Methods 3A or 3C, and noted that these devices are commonly used in practice to measure wellhead parameters and calibrated according to the manufacturer's specifications. Currently, approval of these analyzers are done on a case-by-case basis. In proposed 40 CFR part 60, subpart Cf, the EPA has not listed portable gas composition analyzers for determining oxygen or nitrogen levels. The EPA did not receive any data supporting these comments as to why the analyzers could not be calibrated according to Method 3A and maintains that proper calibration of portable gas composition analyzers is important for generating accurate results. The EPA is requesting data or information on the use of a portable gas composition analyzer according to Method 3A. The EPA is also requesting data on other reference methods used for calibrating these analyzers.
For most Emission Guidelines, the EPA analyzes the impacts in the year the standard is implemented. Assuming the Emission Guidelines are promulgated in the summer of 2016, states have 9 months to prepare a state plan implementing the guidelines (March 2017) and the EPA has 4 months to review the plan (July 2017). If necessary, the state has an additional 2 months to revise and submit a corrected plan based on any comments from the EPA (September 2017). Concurrently, the EPA must promulgate a federal plan within 6 months after the state plan is due, consistent with 60.27(d), or March 2018. So, the EPA-approved state plan and updated federal plan implementing the Emission Guidelines are expected to become effective in March 2018. While 2018 is the estimated implementation year, the proposed reporting and control timeframe allows 3 months to submit the first NMOC emission report and then 30 months after exceeding the NMOC emission threshold before the GCCS is required to be installed. So, the first year of controls under the proposed revisions would be 2021.
The EPA is assessing impacts in year 2025 as a representative year for the landfills Emission Guidelines. While the year 2025 differs somewhat from the expected first year of implementation for the Emission Guidelines (year 2018), the number of existing landfills required to install controls under the proposed 2.5/34 option in year 2025 is comparable (within 2 percent of those required to control in the estimated first year of implementation. Further, year 2025 represents a year in which several of the landfills subject to control requirements have had to expand their GCCS according the expansion lag times set forth in proposed subpart Cf. The methodology for estimating the impacts of the Emission Guidelines is discussed in section V.B of this preamble and in the docketed memorandum “Revised Methodology for Cost and Emission Impacts of Landfill Regulations (2015).” The results of applying this methodology to the population of existing landfills potentially subject to each of the regulatory options are in the docketed memorandum “Revised Cost and Emission Impacts Resulting from the Landfill EG Review (2015).” Table 3 of this preamble summarizes the emission reductions and costs associated with the control options considered.
This proposal would achieve nearly an additional 5 percent reduction in NMOC from existing landfills, or 2,770 Mg/yr, when compared to the baseline, as shown in Table 5 of this preamble. The proposal would also achieve substantial reductions in methane emissions. These reductions are achieved by reducing the NMOC threshold from 50 Mg/yr to 34 Mg/yr as proposed at open landfills.
Leachate is the liquid that passes through the landfilled waste and strips contaminants from the waste as the leachate percolates. Precipitation generates the vast majority of leachate volume. Installation of a gas collection system will generate additional liquid, in the form of gas condensate, and it will be routed to the same leachate treatment mechanisms in place for controlling precipitation-based leachate. Collected leachate can be treated on site or transported off site to wastewater treatment facilities. Some landfills have received permits allowing for recirculation of leachate in the landfill, which may further reduce the volume of leachate requiring treatment. Additional liquid generated from gas condensate is not expected to be significant and insufficient data are available to estimate the increases in leachate resulting from expanded gas collection and control requirements.
The additional GCCS components required by this proposal have finite lifetimes (approximately 15 years) and these pipes and wells will be capped or disposed of at the end of their useful life. There are insufficient data to quantify the solid waste resulting from disposal of this control infrastructure.
Further, the incremental costs of control for the proposal are not expected to have an appreciable market effect on the waste disposal costs, tipping fees, or the amount of solid waste disposed in landfills because the costs for gas collection represent a small portion of the overall costs to design, construct, and operate a landfill. There is insufficient information to quantify the effect increased gas control costs might have on the amount of solid waste disposed of in landfills versus other disposal mechanisms such as recycling, waste-to-energy, or composting. Note that elements of this proposed rule—notably lowering the NMOC threshold to 34 Mg/yr—provide additional incentives to separate waste.
Secondary air impacts may include grid emissions from purchasing electricity to operate the GCCS components, by-product emissions from combustion of LFG in flares or energy recovery devices, and offsets to conventional grid emissions from new LFG energy supply.
The secondary air impacts are presented as net impacts, considering both the energy demand and energy supply resulting from the proposal. The methodology used to prepare the estimated secondary impacts for this preamble is discussed in the docketed memorandum “Estimating Secondary Impacts of the Landfills Emission Guidelines Review. 2015.”
While we do expect NO
The proposal is expected to have a very minimal impact on energy supply and consumption. Active gas collection systems require energy to operate the blowers and pumps and the proposal will increase the volume of landfill gas collected. When the least cost control is a flare, energy may be purchased from the grid to operate the blowers of the landfill gas collection system. However, when the least cost control option is an engine, the engine may provide this energy to the gas control system and then sell the excess to the grid. Considering the balance of energy generated and demanded from the estimated least cost controls, the proposal is estimated to supply 0.4 million megawatt hours (MWh) of additional energy per year.
To meet the proposed control requirements, a landfill is expected to install the least cost control for combusting the landfill gas. The cost estimates (described in sections V of this preamble) evaluated each landfill to determine whether a gas collection and flare or a gas collection with flare and engine equipment would be least cost, after considering local power buyback rates and whether the quantity of landfill gas was sufficient to generate electricity. The control costs include the costs to install and operate gas collection infrastructure such as wells, header pipes, blowers, and an enclosed flare. For landfills where the least cost control option was an engine, the costs also include the cost to install and operate one or more reciprocating internal combustion engines to convert the landfill gas into electricity. Revenue from electricity sales was incorporated into the net control costs using state-specific data on wholesale purchase prices, where engines were deemed to be the least cost control option. Testing and monitoring costs at controlled landfills include the cost to conduct initial performance tests on the enclosed flare or engine control equipment, quarterly surface monitoring, continuous combustion monitoring, and monthly wellhead monitoring. At uncontrolled landfills, the testing and monitoring costs include calculation and reporting of NMOC emission rates.
The nationwide incremental annualized net cost for the proposal is $46.8 million, when using a 7 percent discount rate, of which $0.7 million is testing and monitoring costs. Table 6 of this preamble presents the costs.
Because of the relatively low net cost of the proposed option compared to the overall size of the MSW industry, as well as the lack of appropriate economic parameters or model, the EPA is unable to estimate the impacts of the options on the supply and demand for MSW landfill services. However, because of the relatively low incremental costs of the proposal, the EPA does not believe the proposal would lead to substantial changes in supply and demand for landfill services or waste disposal costs, tipping fees, or the amount of waste disposed in landfills. Hence, the overall economic impact of the proposal should be minimal on the affected industries and their consumers.
The proposal is expected to result in significant emissions reductions from existing MSW landfills. By lowering the NMOC emissions threshold to 34 Mg/yr, the proposal would achieve reductions of 2,770 Mg/yr NMOC and 436,100 Mg/yr methane (10.9 million mtCO
This rule is expected to result in significant health and welfare benefits resulting from the climate benefits due to anticipated methane and CO
As discussed in section IV of this preamble, this rulemaking proposes several changes to the Emission Guidelines for MSW landfills that would decrease methane emissions from this sector. Specifically, the proposed changes are expected to reduce methane emissions from all landfills annually by about 436,100 metric tons of methane.
We estimate the global social benefits of these methane emission reductions using estimates of the social cost of methane (SC-CH
A similar metric, the social cost of CO
The SC-CO
The 2010 SC-CO
The SC-CO
A challenge particularly relevant to this proposal is that the IWG did not estimate the social costs of non-CO
The published literature documents a variety of reasons that directly modeled estimates of SC-CH
In general, the commenters on previous rulemakings strongly encouraged the EPA to incorporate the monetized value of non-CO
Since these previous rulemakings, a paper by Marten et al. (2014) has provided the first set of published SC-CH
The SC-CH
The application of these directly modeled SC-CH
The EPA recently conducted a peer review of the application of the Marten, et al. (2014) non-CO
In light of the favorable peer review and past comments urging the EPA to value non-CO
The CH
The vast majority of this proposal's climate-related benefits are associated with methane reductions. Additional climate-related benefits are expected from the proposal's secondary air impacts, specifically, a net reduction in CO
In addition to the limitation discussed above, and the referenced documents, there are additional impacts of individual GHGs that are not currently captured in the IAMs used in the directly modeled approach of Marten et al. (2014), and therefore not quantified for the rule. For example, the NMOC portion of LFG can contain a variety of air pollutants, including VOC and various organic HAP. VOC emissions are precursors to both PM
Finally, this proposal is also expected to result in improvements in air quality and resulting benefits to human health. With the data available, we are not able to provide health benefit estimates for the reduction in exposure to HAP, ozone, and PM
Although we do not have sufficient information or modeling available to provide quantitative estimates of the health benefits associated with HAP, ozone, and PM
Additional information about these statues and Executive Orders can be found at
This action is an economically significant regulatory action that was submitted to OMB for review. Any changes made in response to OMB recommendations have been documented in the docket. The EPA prepared an economic analysis of the potential costs and benefits associated with the proposed Emission Guidelines. The analysis is documented in the RIA, which is available in docket EPA-HQ-OAR-2014-0451 and is briefly summarized in section V.E of this preamble.
The information collection requirements in the proposed Emission Guidelines have been submitted for approval to OMB under the PRA. The Information Collection Request (ICR) document that the EPA prepared for the proposed Emission Guidelines has been assigned EPA ICR number [2522.01]. You can find a copy of the ICR in the
The information required to be collected is necessary to identify the regulated entities subject to the proposed rule and to ensure their compliance with the proposed Emission Guidelines. The recordkeeping and reporting requirements are mandatory and are being established under authority of CAA section 114 (42 U.S.C. 7414). All information other than emissions data submitted as part of a report to the agency for which a claim of confidentiality is made will be safeguarded according to CAA section 114(c) and the EPA's implementing regulations at 40 CFR part 2, subpart B.
Respondents/affected entities: MSW landfills that accepted waste after November 8, 1987 and commenced construction, reconstruction, or modification on or before July 17, 2014.
Respondent's obligation to respond: Mandatory (40 CFR part 60, subpart Cf).
Estimated number of respondents: 989 MSW landfills.
Frequency of response: Initially, occasionally and annually.
Total estimated burden: 621,947 hours (per year) for the responding facilities and 16,054 hours (per year) for the agency. These are estimates for the average annual burden for the first 3 years after the rule is final. Burden is defined at 5 CFR 1320.3(b).
Total estimated cost: $41,755,793 (per year), which includes annualized capital or operation and maintenance costs, for the responding facilities and $1,029,658 (per year) for the agency. These are estimates for the average annual cost for the first 3 years after the rule is final.
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. The OMB control numbers for the EPA's regulations in 40 CFR are listed in 40 CFR part 9.
Submit your comments on the agency's need for this information, the accuracy of the provided burden estimates and any suggested methods for minimizing respondent burden to the EPA using the docket identified at the beginning of this rule. You may also send your ICR-related comments to OMB's Office of Information and Regulatory Affairs via email to
I certify that this action will not have a significant economic impact on a substantial number of small entities under the RFA. This action 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 and U.S. territories establish standards on existing sources, and it is those state requirements that could potentially impact small entities.
Our analysis here is consistent with the analysis of the analogous situation arising when the EPA establishes National Ambient Air Quality Standards (NAAQS), which do not impose any requirements on regulated entities. As here, 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. See American Trucking Assoc. v. EPA, 175 F.3d 1029, 1043-45 (D.C. Cir. 1999) (NAAQS do not have significant impacts upon small entities because NAAQS themselves impose no regulations upon small entities).
Nevertheless, the EPA is aware that there is substantial interest in the rule among small entities. The EPA has conducted stakeholder outreach as detailed in section XI.C and XI.E of the preamble to the proposed Standards of Performance for MSW Landfills (79 FR 41828-41829; July 17, 2014) and in sections XII.D and XII.E of this preamble. The EPA convened a Small Business Advocacy Review (SBAR) Panel in 2013 for the landfills rulemaking. The EPA originally planned a review of the Emission Guidelines and NSPS in one action, but the actions were subsequently divided into separate rulemakings. The SBAR Panel evaluated the assembled materials and small-entity comments on issues related to the rule's potential effects and significant alternative regulatory approaches. A copy of the Summary of Small Entity Outreach is available in the rulemaking docket EPA-HQ-OAR-2014-0451. While formulating the provisions of the rule, the EPA considered the input provided over the course of the stakeholder outreach as well as the input provided in the many public comments, and we have incorporated many of the suggestions in this proposal.
This action does not contain any unfunded mandate of $100 million or more as described in UMRA, 2 U.S.C. 1531-1538. The proposed Emission Guidelines apply to landfills that were constructed, modified, or reconstructed after November 8, 1987, and that commenced construction, reconstruction, or modification on or before July 17, 2014. Impacts resulting from the proposed Emission Guidelines are below the applicable threshold.
We note however, that the proposed Emission Guidelines may significantly or uniquely affect small governments because small governments operate landfills. The EPA consulted with small governments concerning the regulatory requirements that might significantly or uniquely affect them. In developing this rule, the EPA consulted with small governments pursuant to a plan established under section 203 of the UMRA to address impacts of regulatory requirements in the rule that might significantly or uniquely affect small governments. The EPA also held meetings as discussed in section XII.E of this preamble under Federalism consultations.
The EPA has concluded that the proposed Emission Guidelines have federalism implications, because the rule imposes substantial direct compliance costs on state or local governments, and the federal government will not provide the funds necessary to pay those costs.
The EPA conducted a Federalism Consultation Outreach Meeting on September 10, 2013. Due to interest in that meeting, additional outreach meetings were held on November 7, 2013 and November 14, 2013. With the pending proposal of these Emission Guidelines, an additional Federalism outreach meeting was conducted on April 15, 2015. Participants included the National Governors' Association, the National Conference of State Legislatures, the Council of State Governments, the National League of Cities, the U.S. Conference of Mayors, the National Association of Counties, the International City/County Management Association, the National Association of Towns and Townships, the County Executives of America, the Environmental Council of States, National Association of Clean Air Agencies, Association of State and Territorial Solid Waste Management Officials, environmental agency representatives from 43 states, and
This action has tribal implications. However, it will neither impose substantial direct compliance costs on federally recognized tribal governments, nor preempt tribal law. The database used to estimate impacts of the proposed 40 CFR part 60, subpart Cf identified one tribe, the Salt River Pima-Maricopa Indian Community, which owns three landfills potentially subject to the proposed Emission Guidelines. One of these landfills is open, the Salt River Landfill, and is already controlling emissions under the current NSPS/EG framework, so while subject to this subpart, the costs of this proposal are not substantial. The two other landfills are closed and anticipated to meet the definition of the closed landfill subcategory. One of the closed landfills, the Tri Cities Landfill, is already controlling emissions under the current NSPS/EG framework and will not incur substantial additional compliance costs under Cf. The other landfill, North Center Street Landfill, is not estimated to install controls under the current NSPS/EG framework.
The EPA interprets Executive Order 13045 as applying only to those regulatory actions that concern environmental health or safety risks that the EPA has reason to believe may disproportionately affect children, per the definition of “covered regulatory action” in section 2-202 of the Executive Order. The proposed Emission Guidelines are not subject to Executive Order 13045 because they do not concern an environmental health risk or safety risk. We also note that the methane and NMOC reductions expected from the proposed Emission Guidelines will have positive health effects including for children as previously discussed in section XII.G of this preamble.
This action is not a “significant energy action” because it is not likely to have a significant adverse effect on the supply, distribution, or use of energy. Further, we have concluded that the proposed Emission Guidelines are not likely to have any adverse energy effects because the energy demanded to operate these control systems will be offset by additional energy supply from landfill gas energy projects.
The proposed Emission Guidelines involve technical standards. For the proposed Emission Guidelines, the EPA has decided to use EPA Methods 2, 2E, 3, 3A, 3C, 21, 25, 25A, and 25C of 40 CFR part 60, appendix A. While the EPA identified 10 VCS as being potentially applicable (ANSI/ASME PTC 19-10-1981 Part 10, ASME B133.9-1994 (2001), ISO 10396:1993 (2007), ISO 12039:2001, ASTM D5835-95 (2013), ASTM D6522-11, CAN/CSA Z223.2-M86 (1999), ASTM D6060-96 (2009), ISO 14965:2000(E), EN 12619(1999)), the agency decided not to use these methods. The EPA determined that the 10 candidate VCS identified for measuring emissions of pollutants or their surrogates subject to emission standards in the rule would not be practical due to lack of equivalency, documentation, validation data, and other important technical and policy considerations. The agency identified no such standards for Methods 2E, 21, and 25C. The EPA's review, including review of comments for these 10 methods, is documented in the memorandum, “Voluntary Consensus Standard Results for Emission Guidelines and Compliance Times for Municipal Solid Waste Landfills” in the docket for this rulemaking (EPA-HQ-OAR-2014-0451).
The EPA believes the human health or environmental risk addressed by the proposed Emission Guidelines will not have potential disproportionately high and adverse human health or environmental effects on minority, low-income, or indigenous populations because the proposed subpart would reduce emissions of landfill gas, which contains both nonmethane organic compounds and methane. These avoided emissions will improve air quality and reduce public health and welfare effects associated with exposure to landfill gas emissions. The results of the proximity analysis conducted for the proposed Emission Guidelines are located in the April 22, 2015 document entitled, “2015 Environmental Justice Screening Report for Municipal Solid Waste Landfills,” a copy of which is available in the docket (Docket ID No. EPA-HQ-OAR-2003-0215).
Environmental protection, Administrative practice and procedure, Air pollution control, Reporting and recordkeeping requirements.
For the reasons set forth in the preamble, the EPA proposes to amend 40 CFR part 60 as follows:
42 U.S.C. 7401
This subpart establishes Emission Guidelines and compliance times for the control of designated pollutants from certain designated municipal solid waste (MSW) landfills in accordance with section 111(d) of the Clean Air Act and subpart B of this part.
(a) If you are the Administrator of an air quality program in a State or United States protectorate with one or more existing MSW landfills that commenced construction, modification, or
(b) You must submit a State plan to EPA by [date 9 months after the final rule is published in the
(c) The following authorities will not be delegated to state, local, or tribal agencies:
(1) Approval of alternative methods to determine the NMOC concentration or a site-specific methane generation rate constant (k).
(2) [Reserved]
(a) The designated facility to which these Emission Guidelines apply is each existing MSW landfill for which construction, reconstruction, or modification was commenced on or before July 17, 2014.
(b) Physical or operational changes made to an existing MSW landfill solely to comply with an emission guideline are not considered a modification or reconstruction and would not subject an existing MSW landfill to the requirements of a standard of performance for new MSW landfills.
(c) For purposes of obtaining an operating permit under title V of the Clean Air Act, the owner or operator of an MSW landfill subject to this subpart with a design capacity less than 2.5 million megagrams or 2.5 million cubic meters is not subject to the requirement to obtain an operating permit for the landfill under part 70 or 71 of this chapter, unless the landfill is otherwise subject to either part 70 or 71. For purposes of submitting a timely application for an operating permit under part 70 or 71, the owner or operator of an MSW landfill subject to this subpart with a design capacity greater than or equal to 2.5 million megagrams and 2.5 million cubic meters on the effective date of EPA approval of the State's program under section 111(d) of the Clean Air Act, and not otherwise subject to either part 70 or 71, becomes subject to the requirements of §§ 70.5(a)(1)(i) or 71.5(a)(1)(i) of this chapter 90 days after the effective date of such section 111(d) program approval, even if the design capacity report is submitted earlier.
(d) When an MSW landfill subject to this subpart is closed as defined in this subpart, the owner or operator is no longer subject to the requirement to maintain an operating permit under part 70 or 71 of this chapter for the landfill if the landfill is not otherwise subject to the requirements of either part 70 or 71 and if either of the following conditions are met:
(1) The landfill was never subject to the requirement to install and operate a gas collection and control system under § 60.33f; or
(2) The landfill meets the conditions for control system removal specified in § 60.33f(f).
(e) When an MSW landfill subject to this subpart is in the closed landfill subcategory, the owner or operator is not subject to the following reports of this subpart, provided the owner or operator submitted these reports under the provisions of 40 CFR part 60, subpart WWW; 40 CFR part 62, subpart GGG; or a state plan implementing 40 CFR part 60, subpart Cc on or before August 27, 2015:
(1) Initial design capacity report specified in §§ 60.33f(d) and 60.38f(a)
(2) Initial or subsequent NMOC emission rate report specified in §§ 60.33f(e) and 60.38f(c), provided that the most recent NMOC emission rate report indicated the NMOC emissions were below 50 Mg/yr.
(3) Collection and control system design plan specified in § 60.38f(d).
(4) Closure report specified in § 60.38f(f).
(5) Equipment removal specified in § 60.38f(g).
(6) Initial annual report specified in § 60.38f(h).
(7) Initial performance test report in § 60.38f(i).
Planning, awarding of contracts, installing, and starting up MSW landfill air emission collection and control equipment that is capable of meeting the Emission Guidelines under § 60.33f must be completed within 30 months after the date an NMOC emission rate report shows NMOC emissions equal or exceed 34 megagrams per year (50 megagrams per year for the closed landfill subcategory) or within 30 months after the date Tier 4 surface emissions monitoring shows a surface emission concentration of 500 parts per million methane or greater.
(a)
(1) The landfill has accepted waste at any time since November 8, 1987, or has additional design capacity available for future waste deposition.
(2) The landfill commenced construction, reconstruction, or modification on or before July 17, 2014.
(3) The landfill has an NMOC emission rate greater than or equal to 34 megagrams per year or the Tier 4 surface emissions report shows a surface emission concentration of 500 parts per million methane or greater.
(4) A landfill in the closed landfill subcategory that has an NMOC emission rate greater than or equal to 50 megagrams per year or the Tier 4 surface emissions report shows a surface emission concentration of 500 parts per million methane or greater.
(b)
(1) Install and start up a collection and control system that captures the gas generated within the landfill within 30 months after:
(i) The first annual report in which the emission rate equals or exceeds 34 megagrams per year, unless Tier 2 or Tier 3 sampling demonstrates that the emission rate is less than 34 megagrams per year, as specified in § 60.38f(c)(5)(i) or (ii),
(ii) The emission rate at a landfill in the closed landfill subcategory equals or exceeds 50 megagrams per year, unless Tier 2 or Tier 3 sampling demonstrates that the emission rate is less than 50 megagrams per year, as specified in § 60.38f(c)(5)(iv)(A) or (B), or
(iii) The Tier 4 surface emissions report shows that surface methane emissions are below 500 parts per million methane for four consecutive quarters, as specified in § 60.38f(c)(5)(iii).
(2) An active collection system must:
(i) Be designed to handle the maximum expected gas flow rate from the entire area of the landfill that warrants control over the intended use period of the gas control system equipment.
(ii) Collect gas from each area, cell, or group of cells in the landfill in which the initial solid waste has been placed for a period of 5 years or more if active; or 2 years or more if closed or at final grade.
(iii) Collect gas at a sufficient extraction rate.
(iv) Be designed to minimize offsite migration of subsurface gas.
(3) A passive collection system must:
(i) Comply with the provisions specified in paragraphs (b)(2)(i), (ii), and (iv) of this section.
(ii) Be installed with liners on the bottom and all sides in all areas in which gas is to be collected. The liners must be installed as required under § 258.40.
(c)
(1) A non-enclosed flare designed and operated in accordance with the parameters established in § 60.18 except as noted in § 60.37f(c); or
(2) A control system designed and operated to reduce NMOC by 98 weight percent; or when an enclosed combustion device is used for control, to either reduce NMOC by 98 weight percent or reduce the outlet NMOC concentration to less than 20 parts per million by volume, dry basis as hexane at 3 percent oxygen or less. The reduction efficiency or concentration in parts per million by volume must be established by an initial performance test to be completed no later than 180 days after the initial startup of the approved control system using the test methods specified in § 60.35f(d). The performance test is not required for boilers and process heaters with design heat input capacities equal to or greater than 44 megawatts that burn landfill gas for compliance with this subpart.
(i) If a boiler or process heater is used as the control device, the landfill gas stream must be introduced into the flame zone.
(ii) The control device must be operated within the parameter ranges established during the initial or most recent performance test. The operating parameters to be monitored are specified in § 60.37f.
(iii) For the closed landfill subcategory, the initial or most recent performance test conducted to comply with 40 CFR part 60, subpart WWW; 40 CFR part 62, subpart GGG; or a state plan implementing subpart Cc of this part on or before August 27, 2015 is sufficient for compliance with this subpart.
(3) Route the collected gas to a treatment system that processes the collected gas for subsequent sale or beneficial use such as fuel for combustion, production of vehicle fuel, production of high-Btu gas for pipeline injection, or use as a raw material in a chemical manufacturing process. Venting of treated landfill gas to the ambient air or combustion in a flare is not allowed under this option. (If flares are used, they must meet the requirements in paragraphs (c)(1) or (2) of this section.)
(4) All emissions from any atmospheric vent from the gas treatment system are subject to the requirements of paragraph (b) or (c) of this section. For purposes of this subpart, atmospheric vents located on the condensate storage tank are not part of the treatment system and are exempt from the requirements of paragraph (b) or (c) of this section.
(d)
(1) The owner or operator must submit an amended design capacity report as provided in § 60.38f(b). [Guidance: Note that if the design capacity increase is the result of a modification, as defined in this subpart, that was commenced after July 17, 2014, the landfill will become subject to subpart XXX of this part instead of this subpart. If the design capacity increase is the result of a change in operating practices, density, or some other change that is not a modification as defined in this subpart, then the landfill remains subject to this subpart.]
(2) When an increase in the maximum design capacity of a landfill with an initial design capacity less than 2.5 million megagrams or 2.5 million cubic meters results in a revised maximum design capacity equal to or greater than 2.5 million megagrams and 2.5 million cubic meters, the owner or operator must comply with paragraph (e) of this section.
(e)
(1) If the calculated NMOC emission rate is less than 34 megagrams per year, the owner or operator must:
(i) Submit an annual NMOC emission rate report according to § 60.38f(c); and
(ii) Recalculate the NMOC emission rate annually using the procedures specified in § 60.35f(a) until such time as the calculated NMOC emission rate is equal to or greater than 34 megagrams per year, or the landfill is closed.
(A) If the NMOC emission rate, upon initial calculation or annual recalculation, is equal to or greater than 34 megagrams per year, the owner or operator must either: submit a gas collection and control system design plan as specified in § 60.38f(d) and install a collection and control system as provided in paragraphs (b) and (c) of this section; calculate NMOC emissions using the next higher tier in § 60.35f; or conduct a surface emission monitoring demonstration using the procedures specified in § 60.35f(a)(6).
(B) If the landfill is permanently closed, a closure report must be submitted to the Administrator as provided in § 60.38f(f), except for exemptions allowed under § 60.31f(e)(4).
(C) For the closed landfill subcategory, if the most recently calculated NMOC emission rate is equal to or greater than 50 megagrams per year, the owner or operator must either: submit a gas collection and control system design plan as specified in § 60.38f(d), except for exemptions allowed under 60.31f(e)(3), and install a collection and control system as provided in paragraphs (b) and (c) of this section; calculate NMOC emissions using the next higher tier in § 60.35f; or conduct a surface emission monitoring demonstration using the procedures specified in § 60.35f(a)(6).
(2) If the calculated NMOC emission rate is equal to or greater than 34 megagrams per year using Tier 1, 2, or 3 procedures, the owner or operator must either: submit a collection and control system design plan prepared by a professional engineer to the Administrator within 1 year as specified in § 60.38f(d); calculate NMOC emissions using a higher tier in § 60.35f; or conduct a surface emission monitoring demonstration using the procedures specified in § 60.35f(a)(6).
(3) For the closed landfill subcategory, if the calculated NMOC emission rate is equal to or greater than 50 megagrams per year using Tier 1, 2, or 3 procedures,
(f)
(1) The landfill is closed or an area of an open landfill is closed as defined in § 60.41f. A closure report must be submitted to the Administrator as provided in § 60.38f(f);
(2) The collection and control system must have been in operation a minimum of 15 years or the landfill owner or operator must demonstrate that the GCCS will be unable to operate for 15 years due to declining gas flow; and
(3) The landfill or closed area demonstrates for four consecutive quarters that there are no surface emissions of 500 parts per million or greater as determined using procedures specified in § 60.36f(d);
(4) Following the procedures specified in § 60.35f(b), the calculated NMOC emission rate at the landfill must be less than 34 megagrams per year on three successive test dates. The test dates must be no less than 90 days apart, and no more than 180 days apart; or
(5) For the closed landfill subcategory, following the procedures specified in § 60.35f(b), the calculated NMOC emission rate at the landfill must be less than 50 megagrams per year on three successive test dates. The test dates must be no less than 90 days apart, and no more than 180 days apart.
For approval, a State plan must include provisions for the operational standards in this section for an MSW landfill with a gas collection and control system used to comply with the provisions of § 60.33f(b) and (c). Each owner or operator of an MSW landfill with a gas collection and control system used to comply with the provisions of § 60.33f(b) must:
(a) Operate the collection system such that gas is collected from each area, cell, or group of cells in the MSW landfill in which solid waste has been in place for:
(1) 5 years or more if active; or
(2) 2 years or more if closed or at final grade;
(b) Operate the collection system with negative pressure at each wellhead except under the following conditions:
(1) A fire or increased well temperature. The owner or operator must record instances when positive pressure occurs in efforts to avoid a fire. These records must be submitted with the annual reports as provided in § 60.38f(h)(1);
(2) Use of a geomembrane or synthetic cover. The owner or operator must develop acceptable pressure limits in the design plan;
(3) A decommissioned well. A well may experience a static positive pressure after shut down to accommodate for declining flows. All design changes must be approved by the Administrator as specified in § 60.38f(d);
(c) [Reserved]
(d) Operate the collection system so that the methane concentration is less than 500 parts per million above background at the surface of the landfill. To determine if this level is exceeded, the owner or operator must conduct surface testing around the perimeter of the collection area and along a pattern that traverses the landfill at no more than 30-meter intervals and where visual observations indicate elevated concentrations of landfill gas, such as distressed vegetation and cracks or seeps in the cover and all cover penetrations. Thus, the owner or operator must monitor any openings that are within an area of the landfill where waste has been placed and a gas collection system is required. The owner or operator may establish an alternative traversing pattern that ensures equivalent coverage. A surface monitoring design plan must be developed that includes a topographical map with the monitoring route and the rationale for any site-specific deviations from the 30-meter intervals. Areas with steep slopes or other dangerous areas may be excluded from the surface testing.
(e) Operate the system such that all collected gases are vented to a control system designed and operated in compliance with § 60.33f(c). In the event the collection or control system is not operating, the gas mover system must be shut down and all valves in the collection and control system contributing to venting of the gas to the atmosphere must be closed within 1 hour; and
(f) Operate the control system at all times when the collected gas is routed to the system.
(g) If monitoring demonstrates that the operational requirements in paragraphs (b) or (d) of this section are not met, corrective action must be taken as specified in § 60.36f(a)(3) through (4) or § 60.36f(c). If corrective actions are taken as specified in § 60.36f, the monitored exceedance is not a violation of the operational requirements in this section.
For approval, a State plan must include provisions in this section to calculate the landfill NMOC emission rate or to conduct a surface emission monitoring demonstration.
(a)(1) The landfill owner or operator must calculate the NMOC emission rate using either the equation provided in paragraph (a)(1)(i) of this section or the equation provided in paragraph (a)(1)(ii) of this section. Both equations may be used if the actual year-to-year solid waste acceptance rate is known, as specified in paragraph (a)(1)(i) of this section, for part of the life of the landfill and the actual year-to-year solid waste acceptance rate is unknown, as specified in paragraph (a)(1)(ii) of this section, for part of the life of the landfill. The values to be used in both equations are 0.05 per year for k, 170 cubic meters per megagram for Lo, and 4,000 parts per million by volume as hexane for the CNMOC. For landfills located in geographical areas with a 30-year annual average precipitation of less than 25 inches, as measured at the nearest representative official meteorologic site, the k value to be used is 0.02 per year.
(i)(A) The following equation must be used if the actual year-to-year solid waste acceptance rate is known.
(B) The mass of nondegradable solid waste may be subtracted from the total mass of solid waste in a particular section of the landfill when calculating the value for Mi if documentation of the nature and amount of such wastes is maintained.
(ii)(A) The following equation must be used if the actual year-to-year solid waste acceptance rate is unknown.
(B) The mass of nondegradable solid waste may be subtracted from the total mass of solid waste in a particular section of the landfill when calculating the value of R, if documentation of the nature and amount of such wastes is maintained.
(2)
(i) If the NMOC emission rate calculated in paragraph (a)(1) of this section is less than 34 megagrams per year, then the owner or operator must submit an NMOC emission rate report according to § 60.38f(c), and must recalculate the NMOC mass emission rate annually as required under § 60.33f(e).
(ii) If the NMOC emission rate calculated in paragraph (a)(1) of this section is equal to or greater than 34 megagrams per year, then the landfill owner or operator must either:
(A) Submit a gas collection and control system design plan as specified in § 60.38f(d) within 1 year and install and operate a gas collection and control system according to § 60.33f(b) and (c) within 30 months;
(B) Determine a site-specific NMOC concentration and recalculate the NMOC emission rate using the Tier 2 procedures provided in paragraph (a)(3) of this section;
(C) Determine a site-specific methane generation rate constant and recalculate the NMOC emission rate using the Tier 3 procedures provided in paragraph (a)(4) of this section; or
(D) Conduct a surface emission monitoring demonstration using the Tier 4 procedures specified in paragraph (a)(6) of this section.
(3)
(i) Within 60 days after the date of determining the NMOC concentration and corresponding NMOC emission rate, the owner or operator must submit the results according to § 60.38f(j).
(ii) The landfill owner or operator must recalculate the NMOC mass emission rate using the equations provided in paragraph (a)(1)(i) or (a)(1)(ii) of this section using the average site-specific NMOC concentration from the collected samples instead of the default value provided in paragraph (a)(1) of this section.
(iii) If the NMOC mass emission rate is less than 34 megagrams per year, then the owner or operator must submit an NMOC emission rate report according to § 60.38f(c), and must recalculate the NMOC mass emission rate annually as required under § 60.33f(e). The site-specific NMOC concentration must be retested every 5 years using the methods specified in this section.
(iv) If the NMOC mass emission rate as calculated using the Tier 2 site-specific NMOC concentration is equal to or greater than 34 megagrams per year, the owner or operator must either:
(A) Submit a gas collection and control system design plan as specified in § 60.38f(d) within 1 year and install and operate a gas collection and control system according to § 60.33f(b) and (c) within 30 months;
(B) Determine a site-specific methane generation rate constant and recalculate the NMOC emission rate using the site-specific methane generation rate using the Tier 3 procedures specified in paragraph (a)(4) of this section; or
(C) Conduct a surface emission monitoring demonstration using the Tier 4 procedures specified in paragraph (a)(6) of this section.
(4)
(i) If the NMOC mass emission rate as calculated using the Tier 2 site-specific NMOC concentration and Tier 3 site-specific methane generation rate is equal to or greater than 34 megagrams per year, the owner or operator must either:
(A) Submit a gas collection and control system design plan as specified in § 60.38f(d) within 1 year and install and operate a gas collection and control
(B) Conduct a surface emission monitoring demonstration using the Tier 4 procedures specified in paragraph (a)(6) of this section.
(ii) If the NMOC mass emission rate is less than 34 megagrams per year, then the owner or operator must recalculate the NMOC mass emission rate annually using the equations in paragraph (a)(1) of this section and using the site-specific Tier 2 NMOC concentration and Tier 3 methane generation rate constant and submit a periodic emission rate report as provided in § 60.38f(c). The calculation of the methane generation rate constant is performed only once, and the value obtained from this test must be used in all subsequent annual NMOC emission rate calculations.
(5) The owner or operator may use other methods to determine the NMOC concentration or a site-specific methane generation rate constant as an alternative to the methods required in paragraphs (a)(3) and (a)(4) of this section if the method has been approved by the Administrator.
(6)
(i) The owner or operator must measure surface concentrations of methane along the entire perimeter of the landfill and along a pattern that traverses the landfill at no more than 30-meter intervals using an organic vapor analyzer, flame ionization detector, or other portable monitor meeting the specifications provided in paragraph (a)(6)(iv) of this section.
(ii) The background concentration must be determined by moving the probe inlet upwind and downwind at least 30 meters from the waste mass boundary of the landfill.
(iii) Surface emission monitoring must be performed in accordance with section 8.3.1 of Method 21 of appendix A of this part, except that the probe inlet must be placed within 5 to 10 centimeters of the landfill surface. Monitoring must be performed during typical meteorological conditions.
(A) Surface emission monitoring must be terminated when the average wind speed exceeds 5 miles per hour or the instantaneous wind speed exceeds 10 miles per hour. The Administrator may approve alternatives to this wind speed surface monitoring termination for landfills consistently having measured winds in excess of these specified limits. Average wind speed must be determined on a 15-minute average using an onsite anemometer with a continuous recorder for the entire duration of the monitoring event.
(B) Landfill surface areas where visual observations indicate elevated concentrations of landfill gas, such as distressed vegetation and cracks or seeps in the cover, and all cover penetrations must also be monitored using a device meeting the specifications provided in paragraph (a)(6)(iv) of this section.
(iv) Each owner or operator seeking to comply with the provisions in paragraph (a)(6) of this section must comply with the following instrumentation specifications and procedures for surface emission monitoring devices.
(A) The portable analyzer must meet the instrument specifications provided in section 3 of Method 21 of appendix A of this part, except that “methane” replaces all references to “VOC”.
(B) The calibration gas is methane, diluted to a nominal concentration of 500 parts per million in air.
(C) To meet the performance evaluation requirements in section 3.1.3 of Method 21 of appendix A of this part, the instrument evaluation procedures of section 4.4 of Method 21 of appendix A of this part must be used.
(D) The calibration procedures provided in section 4.2 of Method 21 of appendix A of this part must be followed immediately before commencing a surface monitoring survey.
(v) Each owner or operator seeking to comply with the Tier 4 provisions in paragraph (a)(6) of this section must maintain records of surface emission monitoring as provided in § 60.39f(g) and submit a Tier 4 surface emissions report as provided in § 60.38f(c)(5)(iii).
(vi) If there is any measured concentration of methane of 500 parts per million or greater from the surface of the landfill, the owner or operator must submit a gas collection and control system design plan within 1 year of the first measured concentration of methane of 500 parts per million or greater from the surface of the landfill according to § 60.38f(d) and install and operate a gas collection and control system according to § 60.33f(b) and (c) within 30 months of the first measured concentration of methane of 500 parts per million or greater from the surface of the landfill.
(vii) If after four consecutive quarterly monitoring periods there is no measured concentration of methane of 500 parts per million or greater from the surface of the landfill, the owner or operator must either conduct semi-annual surface emission monitoring using the methods specified in this section or recalculate the NMOC mass emission rate annually as provided in § 60.33f(e).
(A) If conducting semi-annual surface emissions monitoring and there is any measured concentration of methane of 500 parts per million or greater from the surface of the landfill, the owner or operator must submit a gas collection and control system design plan within 1 year of the first measured concentration of methane of 500 parts per million or greater from the surface of the landfill according to § 60.38f(d) and install and operate a gas collection and control system according to § 60.33f(b) and (c) within 30 months of the first measured concentration of methane of 500 parts per million or greater from the surface of the landfill.
(B) [Reserved]
(b) After the installation and startup of a collection and control system in compliance with this subpart, the owner or operator must calculate the NMOC emission rate for purposes of determining when the system can be capped or removed as provided in § 60.33f(f), using the following equation:
(1) The flow rate of landfill gas, Q
(2) The average NMOC concentration, C
(3) The owner or operator may use another method to determine landfill gas flow rate and NMOC concentration if the method has been approved by the Administrator.
(i) Within 60 days after the date of calculating the NMOC emission rate for purposes of determining when the
(ii) [Reserved]
(c) When calculating emissions for Prevention of Significant Deterioration (PSD) purposes, the owner or operator of each MSW landfill subject to the provisions of this subpart must estimate the NMOC emission rate for comparison to the PSD major source and significance levels in §§ 51.166 or 52.21 of this chapter using Compilation of Air Pollutant Emission Factors, Volume I: Stationary Point and Area Sources (AP-42) or other approved measurement procedures.
(d) For the performance test required in § 60.33f(c)(1), the net heating value of the combusted landfill gas as determined in § 60.18(f)(3) is calculated from the concentration of methane in the landfill gas as measured by Method 3C. A minimum of three 30-minute Method 3C samples are determined. The measurement of other organic components, hydrogen, and carbon monoxide is not applicable. Method 3C may be used to determine the landfill gas molecular weight for calculating the flare gas exit velocity under § 60.18(f)(4).
(1) Within 60 days after the date of completing each performance test (as defined in § 60.8), the owner or operator must submit the results of the performance tests required by § 60.35f(b) or (d), including any associated fuel analyses, according to § 60.38f(j).
(2) [Reserved]
(e) For the performance test required in § 60.33f(c)(2), Method 25 or 25C (Method 25C may be used at the inlet only) of appendix A of this part must be used to determine compliance with the 98 weight-percent efficiency or the 20 parts per million by volume outlet NMOC concentration level, unless another method to demonstrate compliance has been approved by the Administrator as provided by § 60.38f(d). Method 3 or 3A must be used to determine oxygen for correcting the NMOC concentration as hexane to 3 percent. In cases where the outlet concentration is less than 50 ppm NMOC as carbon (8 ppm NMOC as hexane), Method 25A should be used in place of Method 25. The following equation must be used to calculate efficiency:
(1) Within 60 days after the date of completing each performance test (as defined in § 60.8), the owner or operator must submit the results of the performance tests, including any associated fuel analyses, according to § 60.38f(j).
(2) [Reserved]
For approval, a State plan must include the compliance provisions in this section.
(a) Except as provided in § 60.38f(d)(2), the specified methods in paragraphs (a)(1) through (6) of this section must be used to determine whether the gas collection system is in compliance with § 60.33f(b)(2).
(1) For the purposes of calculating the maximum expected gas generation flow rate from the landfill to determine compliance with § 60.33f(b)(2)(i), one of the following equations must be used. The k and Lo kinetic factors should be those published in the most recent AP-42 or other site-specific values demonstrated to be appropriate and approved by the Administrator. If k has been determined as specified in § 60.35f(a)(4), the value of k determined from the test must be used. A value of no more than 15 years must be used for the intended use period of the gas mover equipment. The active life of the landfill is the age of the landfill plus the estimated number of years until closure.
(i) For sites with unknown year-to-year solid waste acceptance rate:
(ii) For sites with known year-to-year solid waste acceptance rate:
(iii) If a collection and control system has been installed, actual flow data may be used to project the maximum expected gas generation flow rate instead of, or in conjunction with, the equations in paragraphs (a)(1)(i) and (ii) of this section. If the landfill is still accepting waste, the actual measured flow data will not equal the maximum expected gas generation rate, so calculations using the equations in paragraphs (a)(1)(i) or (ii) of this section or other methods must be used to predict the maximum expected gas generation rate over the intended period of use of the gas control system equipment.
(2) For the purposes of determining sufficient density of gas collectors for compliance with § 60.33f(b)(2)(ii), the owner or operator must design a system of vertical wells, horizontal collectors, or other collection devices, satisfactory to the Administrator, capable of controlling and extracting gas from all portions of the landfill sufficient to meet all operational and performance standards.
(3) For the purpose of demonstrating whether the gas collection system flow rate is sufficient to determine compliance with § 60.33f(b)(2)(iii), the owner or operator must measure gauge pressure in the gas collection header applied to each individual well monthly. If a positive pressure exists, action must be initiated to correct the exceedance within 5 calendar days, except for the three conditions allowed under § 60.34f(b). If negative pressure cannot be achieved without excess air infiltration within 15 calendar days of the first measurement, the gas collection system must be expanded to correct the exceedance within 120 days of the initial measurement of positive pressure. Any attempted corrective measure must not cause exceedances of other operational or performance standards. An alternative timeline for correcting the exceedance may be submitted to the Administrator for approval.
(4) Owners or operators are not required to expand the system as required in paragraph (a)(3) of this section during the first 180 days after gas collection system startup.
(5) [Reserved]
(6) An owner or operator seeking to demonstrate compliance with § 60.33f(b)(2)(iv) through the use of a collection system not conforming to the specifications provided in § 60.40f must provide information satisfactory to the Administrator as specified in
(b) For purposes of compliance with § 60.34f(a), each owner or operator of a controlled landfill must place each well or design component as specified in the approved design plan as provided in § 60.38f(d). Each well must be installed no later than 60 days after the date on which the initial solid waste has been in place for a period of:
(1) 5 years or more if active; or
(2) 2 years or more if closed or at final grade.
(c) The following procedures must be used for compliance with the surface methane operational standard as provided in § 60.34f(d):
(1) After installation and startup of the gas collection system, the owner or operator must monitor surface concentrations of methane along the entire perimeter of the collection area and along a pattern that traverses the landfill at no more than 30-meter intervals (or a site-specific established spacing) for each collection area on a quarterly basis using an organic vapor analyzer, flame ionization detector, or other portable monitor meeting the specifications provided in § 60.36f(d).
(2) The background concentration must be determined by moving the probe inlet upwind and downwind outside the boundary of the landfill at a distance of at least 30 meters from the perimeter wells.
(3) Surface emission monitoring must be performed in accordance with section 8.3.1 of Method 21 of appendix A of this part, except that the probe inlet must be placed within 5 to 10 centimeters of the ground. Monitoring must be performed during typical meteorological conditions.
(4) Any reading of 500 parts per million or more above background at any location must be recorded as a monitored exceedance and the actions specified in paragraphs (c)(4)(i) through (v) of this section must be taken. As long as the specified actions are taken, the exceedance is not a violation of the operational requirements of § 60.34f(d).
(i) The location of each monitored exceedance must be marked and the location and concentration recorded. For location, you must determine the latitude and longitude coordinates using an instrument with an accuracy of at least 3 meters. Your coordinates must be in decimal degrees with at least five decimal places.
(ii) Cover maintenance or adjustments to the vacuum of the adjacent wells to increase the gas collection in the vicinity of each exceedance must be made and the location must be re-monitored within 10 calendar days of detecting the exceedance.
(iii) If the re-monitoring of the location shows a second exceedance, additional corrective action must be taken and the location must be monitored again within 10 days of the second exceedance. If the re-monitoring shows a third exceedance for the same location, the action specified in paragraph (c)(4)(v) of this section must be taken, and no further monitoring of that location is required until the action specified in paragraph (c)(4)(v) of this section has been taken.
(iv) Any location that initially showed an exceedance but has a methane concentration less than 500 parts per million methane above background at the 10-day re-monitoring specified in paragraph (c)(4)(ii) or (iii) of this section must be re-monitored 1 month from the initial exceedance. If the 1-month re-monitoring shows a concentration less than 500 parts per million above background, no further monitoring of that location is required until the next quarterly monitoring period. If the 1-month re-monitoring shows an exceedance, the actions specified in paragraph (c)(4)(iii) or (v) of this section must be taken.
(v) For any location where monitored methane concentration equals or exceeds 500 parts per million above background three times within a quarterly period, a new well or other collection device must be installed within 120 calendar days of the initial exceedance. An alternative remedy to the exceedance, such as upgrading the blower, header pipes or control device, and a corresponding timeline for installation may be submitted to the Administrator for approval.
(5) The owner or operator must implement a program to monitor for cover integrity and implement cover repairs as necessary on a monthly basis.
(d) Each owner or operator seeking to comply with the provisions in paragraph (c) of this section must comply with the following instrumentation specifications and procedures for surface emission monitoring devices:
(1) The portable analyzer must meet the instrument specifications provided in section 3 of Method 21 of appendix A of this part, except that “methane” must replace all references to “VOC”.
(2) The calibration gas must be methane, diluted to a nominal concentration of 500 parts per million in air.
(3) To meet the performance evaluation requirements in section 3.1.3 of Method 21 of appendix A of this part, the instrument evaluation procedures of section 4.4 of Method 21 of appendix A of this part must be used.
(4) The calibration procedures provided in section 4.2 of Method 21 of appendix A of this part must be followed immediately before commencing a surface monitoring survey.
(e) The provisions of this subpart apply at all times, including periods of startup, shutdown or malfunction.
For approval, a State plan must include the monitoring provisions in this section, except as provided in § 60.38f(d)(2).
(a) Each owner or operator seeking to comply with § 60.33f(b)(2) for an active gas collection system must install a sampling port and a thermometer, other temperature measuring device, or an access port for temperature measurements at each wellhead and:
(1) Measure the gauge pressure in the gas collection header on a monthly basis as provided in § 60.36f(a)(3); and
(2) Monitor nitrogen or oxygen concentration in the landfill gas on a monthly basis as follows:
(i) The nitrogen level must be determined using Method 3C, unless an alternative test method is established as allowed by § 60.38f(d)(2).
(ii) Unless an alternative test method is established as allowed by § 60.38f(d)(2), the oxygen must be determined by an oxygen meter using Method 3A or 3C except that:
(A) The span must be set between 10 and 12 percent oxygen;
(B) A data recorder is not required;
(C) Only two calibration gases are required, a zero and span;
(D) A calibration error check is not required;
(E) The allowable sample bias, zero drift, and calibration drift are ±10 percent.
(3) Monitor temperature of the landfill gas on a monthly basis. The temperature measuring device must be calibrated annually using the procedure in 40 CFR part 60, Appendix A-1, Method 2, Section 10.3.
(b) Each owner or operator seeking to comply with § 60.33f(c) using an enclosed combustor must calibrate, maintain, and operate according to the manufacturer's specifications, the following equipment:
(1) A temperature monitoring device equipped with a continuous recorder and having a minimum accuracy of ±1 percent of the temperature being measured expressed in degrees Celsius or ±0.5 degrees Celsius, whichever is greater. A temperature monitoring device is not required for boilers or
(2) A device that records flow to or bypass of the control device. The owner or operator must:
(i) Install, calibrate, and maintain a gas flow rate measuring device that must record the flow to the control device at least every 15 minutes; and
(ii) Secure the bypass line valve in the closed position with a car-seal or a lock-and-key type configuration. A visual inspection of the seal or closure mechanism must be performed at least once every month to ensure that the valve is maintained in the closed position and that the gas flow is not diverted through the bypass line.
(c) Each owner or operator seeking to comply with § 60.33f(c) using a non-enclosed flare must install, calibrate, maintain, and operate according to the manufacturer's specifications the following equipment:
(1) A heat sensing device, such as an ultraviolet beam sensor or thermocouple, at the pilot light or the flame itself to indicate the continuous presence of a flame.
(2) A device that records flow to or bypass of the flare. The owner or operator must:
(i) Install, calibrate, and maintain a gas flow rate measuring device that must record the flow to the control device at least every 15 minutes; and
(ii) Secure the bypass line valve in the closed position with a car-seal or a lock-and-key type configuration. A visual inspection of the seal or closure mechanism must be performed at least once every month to ensure that the valve is maintained in the closed position and that the gas flow is not diverted through the bypass line.
(d) Each owner or operator seeking to demonstrate compliance with § 60.33f(c) using a device other than a non-enclosed flare or an enclosed combustor or a treatment system must provide information satisfactory to the Administrator as provided in § 60.38f(d)(2) describing the operation of the control device, the operating parameters that would indicate proper performance, and appropriate monitoring procedures. The Administrator must review the information and either approve it, or request that additional information be submitted. The Administrator may specify additional appropriate monitoring procedures.
(e) Each owner or operator seeking to install a collection system that does not meet the specifications in § 60.40f or seeking to monitor alternative parameters to those required by § 60.34f through § 60.37f must provide information satisfactory to the Administrator as provided in § 60.38f(d)(2) and (3) describing the design and operation of the collection system, the operating parameters that would indicate proper performance, and appropriate monitoring procedures. The Administrator may specify additional appropriate monitoring procedures.
(f) Each owner or operator seeking to demonstrate compliance with the 500 parts per million surface methane operational standard in § 60.34f(d) must monitor surface concentrations of methane according to the procedures provided in § 60.36f(c) and the instrument specifications in § 60.36f(d). Any closed landfill that has no monitored exceedances of the operational standard in three consecutive quarterly monitoring periods may skip to annual monitoring. Any methane reading of 500 parts per million or more above background detected during the annual monitoring returns the frequency for that landfill to quarterly monitoring.
(g) Each owner or operator seeking to demonstrate compliance with the control system requirements in § 60.33f(c) using a landfill gas treatment system must calibrate, maintain, and operate according to the manufacturer's specifications a device that records flow to or bypass of the treatment system. The owner or operator must:
(1) Install, calibrate, and maintain a gas flow rate measuring device that records the flow to the treatment system at least every 15 minutes; and
(2) Secure the bypass line valve in the closed position with a car-seal or a lock-and-key type configuration. A visual inspection of the seal or closure mechanism must be performed at least once every month to ensure that the valve is maintained in the closed position and that the gas flow is not diverted through the bypass line.
For approval, a State plan must include the reporting provisions listed in this section, as applicable, except as provided under §§ 60.24 and 60.38f(d)(2).
(a)
(1) A map or plot of the landfill, providing the size and location of the landfill, and identifying all areas where solid waste may be landfilled according to the permit issued by the state, local, or tribal agency responsible for regulating the landfill.
(2) The maximum design capacity of the landfill. Where the maximum design capacity is specified in the permit issued by the state, local, or tribal agency responsible for regulating the landfill, a copy of the permit specifying the maximum design capacity may be submitted as part of the report. If the maximum design capacity of the landfill is not specified in the permit, the maximum design capacity must be calculated using good engineering practices. The calculations must be provided, along with the relevant parameters as part of the report. The landfill may calculate design capacity in either megagrams or cubic meters for comparison with the exemption values. If the owner or operator chooses to convert the design capacity from volume to mass or from mass to volume to demonstrate its design capacity is less than 2.5 million megagrams or 2.5 million cubic meters, the calculation must include a site-specific density, which must be recalculated annually. Any density conversions must be documented and submitted with the design capacity report. The state, local, or tribal agency or the Administrator may request other reasonable information as may be necessary to verify the maximum design capacity of the landfill.
(b)
(c)
(1) The NMOC emission rate report must contain an annual or 5-year estimate of the NMOC emission rate calculated using the formula and procedures provided in § 60.35f(a).
(2) The NMOC emission rate report must include all the data, calculations, sample reports and measurements used to estimate the annual or 5-year emissions.
(3) If the estimated NMOC emission rate as reported in the annual report to the Administrator is less than 34 megagrams per year in each of the next 5 consecutive years, the owner or operator may elect to submit, following the procedure specified in paragraph (j) of this section, an estimate of the NMOC emission rate for the next 5-year period in lieu of the annual report. This estimate must include the current amount of solid waste-in-place and the estimated waste acceptance rate for each year of the 5 years for which an NMOC emission rate is estimated. All data and calculations upon which this estimate is based must be provided to the Administrator. This estimate must be revised at least once every 5 years. If the actual waste acceptance rate exceeds the estimated waste acceptance rate in any year reported in the 5-year estimate, a revised 5-year estimate must be submitted to the Administrator. The revised estimate must cover the 5-year period beginning with the year in which the actual waste acceptance rate exceeded the estimated waste acceptance rate.
(4) Each owner or operator subject to the requirements of this subpart is exempted from the requirements to submit an NMOC emission rate report, after installing a collection and control system that complies with § 60.33f(b) and (c), during such time as the collection and control system is in operation and in compliance with §§ 60.34f and 60.36f.
(5) Each owner or operator of an MSW landfill having a design capacity equal to or greater than 2.5 million megagrams and 2.5 million cubic meters must submit a collection and control system design plan to the Administrator within 1 year of the first NMOC emission rate report in which the NMOC emission rate equals or exceeds 34 megagrams per year, except as follows:
(i) If the owner or operator elects to recalculate the NMOC emission rate after Tier 2 NMOC sampling and analysis as provided in § 60.35f(a)(3) and the resulting rate is less than 34 megagrams per year, annual periodic reporting must be resumed, using the Tier 2 determined site-specific NMOC concentration, until the calculated emission rate is equal to or greater than 34 megagrams per year or the landfill is closed. The revised NMOC emission rate report, with the recalculated emission rate based on NMOC sampling and analysis, must be submitted, following the procedure specified in paragraph (j) of this section, within 180 days of the first calculated exceedance of 34 megagrams per year.
(ii) If the owner or operator elects to recalculate the NMOC emission rate after determining a site-specific methane generation rate constant k, as provided in Tier 3 in § 60.35f(a)(4), and the resulting NMOC emission rate is less than 34 megagrams per year, annual periodic reporting must be resumed. The resulting site-specific methane generation rate constant k must be used in the emission rate calculation until such time as the emissions rate calculation results in an exceedance. The revised NMOC emission rate report based on the provisions of § 60.35f(a)(4) and the resulting site-specific methane generation rate constant k must be submitted, following the procedure specified in paragraph (j) of this section, to the Administrator within 1 year of the first calculated NMOC emission rate equaling or exceeding 34 megagrams per year.
(iii) If the owner or operator elects to demonstrate that site-specific surface methane emissions are below 500 parts per million methane, then the owner or operator must submit annually a Tier 4 surface emissions report as specified in this paragraph following the procedure specified in paragraph (j) of this section. If the Tier 4 surface emissions report shows no surface emissions readings of 500 parts per million methane or greater for four consecutive quarters, then the landfill may continue Tier 4 monitoring at a reduced semi-annual frequency or return to Tier 1, 2, or 3. An owner or operator may elect to recalculate NMOC using Tier 1, 2, or 3 only if it has four consecutive quarters with no surface emissions monitoring readings of 500 parts per million or greater. The NMOC emission rate report must be submitted annually, following the procedure specified in paragraph (j) of this section, except as provided for in paragraph (c)(3) of this section. The Administrator may request such additional information as may be necessary to verify the reported instantaneous surface emission readings. The Tier 4 surface emissions report must clearly identify the location, date, and reading (in parts per million) of any value 500 parts per million methane or greater, other than non-repeatable, momentary readings. For location, you must determine the latitude and longitude coordinates using an instrument with an accuracy of at least 3 meters. Your coordinates must be in decimal degrees with at least five decimal places.
(iv) If the landfill is in the closed landfill subcategory, the owner or operator must submit a collection and control system design plan to the Administrator within 1 year of the first NMOC emission rate report in which the NMOC emission rate equals or exceeds 50 megagrams per year, except as follows:
(A) If the owner or operator elects to recalculate the NMOC emission rate after Tier 2 NMOC sampling and analysis as provided in § 60.35f(a)(3) and the resulting rate is less than 50 megagrams per year, annual periodic reporting must be resumed, using the Tier 2 determined site-specific NMOC concentration, until the calculated emission rate is equal to or greater than 50 megagrams per year or the landfill is closed. The revised NMOC emission rate report, with the recalculated emission rate based on NMOC sampling and analysis, must be submitted, following the procedure specified in paragraph (j) of this section, within 180 days of the first calculated exceedance of 50 megagrams per year.
(B) If the owner or operator elects to recalculate the NMOC emission rate after determining a site-specific methane generation rate constant k, as provided in Tier 3 in § 60.35f(a)(4), and the resulting NMOC emission rate is less than 50 megagrams per year, annual periodic reporting must be resumed. The resulting site-specific methane generation rate constant k must be used in the emission rate calculation until such time as the emissions rate calculation results in an exceedance. The revised NMOC emission rate report based on the provisions of § 60.35f(a)(4) and the resulting site-specific methane generation rate constant k must be submitted, following the procedure specified in paragraph (j) of this section, to the Administrator within 1 year of the first calculated NMOC emission rate equaling or exceeding 50 megagrams per year.
(C) The landfill owner or operator elects to demonstrate surface emissions are low, consistent with the provisions in § 60.38(c)(5)(iii).
(D) The landfill has already submitted a gas collection and control system design plan consistent with the provisions of subpart WWW of this part; 40 CFR part 62, subpart GGG; or a state plan implementing subpart Cc of this part.
(d)
(1) The collection and control system as described in the design plan must meet the design requirements in § 60.33f(b) and (c).
(2) The collection and control system design plan must include any alternatives to the operational standards, test methods, procedures, compliance measures, monitoring, recordkeeping, or reporting provisions of §§ 60.34f through 60.39f proposed by the owner or operator.
(3) The collection and control system design plan must either conform to specifications for active collection systems in § 60.40f or include a demonstration to the Administrator's satisfaction of the sufficiency of the alternative provisions to § 60.40f.
(4) If the owner or operator chooses to demonstrate compliance with the emission control requirements of this subpart using a treatment system as defined in this subpart, then the owner or operator must prepare a site-specific treatment system monitoring plan as specified in § 60.39f(b)(5)(ii).
(5) The Administrator must review the information submitted under paragraphs (d)(1) through (4) of this section and either approve it, disapprove it, or request that additional information be submitted. Because of the many site-specific factors involved with landfill gas system design, alternative systems may be necessary. A wide variety of system designs are possible, such as vertical wells, combination horizontal and vertical collection systems, or horizontal trenches only, leachate collection components, and passive systems.
(e)
(1) Within 90 days of expanding operations to an area not covered by the previously approved design plan.
(2) Prior to installing or expanding the gas collection system in a way that is not consistent with the design plan that was submitted to the Administrator according to paragraph (d) of this section.
(f)
(g)
(1) The equipment removal report must contain the following items:
(i) A copy of the closure report submitted in accordance with paragraph (f) of this section; and
(ii) A copy of the initial performance test report demonstrating that the 15-year minimum control period has expired, unless the report of the results of the performance test has been submitted to the EPA via the EPA's CDX, or information that demonstrates that the GCCS will be unable to operate for 15 years due to declining gas flows. In the equipment removal report, the process unit(s) tested, the pollutant(s) tested, and the date that such performance test was conducted may be submitted in lieu of the performance test report if the report has been previously submitted to the EPA's CDX; and
(iii) Dated records of surface emissions monitoring data of the landfill or closed area that demonstrates that there are no surface emissions of 500 parts per million or greater for four consecutive quarters, unless the reports have been submitted to the EPA via the EPA's CDX. If the surface emissions monitoring reports have been previously submitted to the EPA's CDX, a statement that the reports have been submitted electronically and the dates that the reports were submitted to the EPA's CDX may be submitted in the equipment removal report in lieu of the surface emissions monitoring reports; or
(iv) Dated copies of three successive NMOC emission rate reports demonstrating that the landfill is no longer producing 34 megagrams or greater of NMOC per year; or
(v) For the closed landfill subcategory, dated copies of three successive NMOC emission rate reports demonstrating that the landfill is no longer producing 50 megagrams or greater of NMOC per year.
(2) The Administrator may request such additional information as may be necessary to verify that all of the conditions for removal in § 60.33f(f) have been met.
(h)
(1) Value and length of time for exceedance of applicable parameters monitored under § 60.37f(a)(1), (b), (c), (d), and (g).
(2) Description and duration of all periods when the gas stream is diverted from the control device or treatment system through a bypass line or the indication of bypass flow as specified under § 60.37f.
(3) Description and duration of all periods when the control device or treatment system was not operating and length of time the control device or treatment system was not operating.
(4) All periods when the collection system was not operating.
(5) The location of each exceedance of the 500 parts per million methane concentration as provided in § 60.34f(d) and the concentration recorded at each location for which an exceedance was recorded in the previous month. For location, you must determine the latitude and longitude coordinates using an instrument with an accuracy of at least 3 meters. Your coordinates must be in decimal degrees with at least five decimal places.
(6) The date of installation and the location of each well or collection system expansion added pursuant to § 60.36f(a)(3), (b), and (c)(4).
(i)
(1) A diagram of the collection system showing collection system positioning including all wells, horizontal collectors, surface collectors, or other gas extraction devices, including the locations of any areas excluded from collection and the proposed sites for the future collection system expansion;
(2) The data upon which the sufficient density of wells, horizontal collectors, surface collectors, or other gas extraction devices and the gas mover equipment sizing are based;
(3) The documentation of the presence of asbestos or nondegradable material for each area from which collection wells have been excluded based on the presence of asbestos or nondegradable material;
(4) The sum of the gas generation flow rates for all areas from which collection wells have been excluded based on nonproductivity and the calculations of gas generation flow rate for each excluded area;
(5) The provisions for increasing gas mover equipment capacity with increased gas generation flow rate, if the present gas mover equipment is inadequate to move the maximum flow rate expected over the life of the landfill; and
(6) The provisions for the control of offsite migration.
(j)
(1) For data collected using test methods supported by the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT Web site (
(2) For data collected using test methods that are not supported by the EPA's ERT as listed on the EPA's ERT Web site, you must submit the results of the performance test to the Administrator at the appropriate address listed in § 60.4.
For approval, a State plan must include the recordkeeping provisions in this section.
(a) Except as provided in § 60.38f(d)(2), each owner or operator of an MSW landfill subject to the provisions of § 60.33f(e) must keep for at least 5 years up-to-date, readily accessible, onsite records of the design capacity report that triggered § 60.33f(e), the current amount of solid waste in-place, and the year-by-year waste acceptance rate. Offsite records may be maintained if they are retrievable within 4 hours. Either paper copy or electronic formats are acceptable.
(b) Except as provided in § 60.38f(d)(2), each owner or operator of a controlled landfill must keep up-to-date, readily accessible records for the life of the control system equipment of the data listed in paragraphs (b)(1) through (b)(5) of this section as measured during the initial performance test or compliance determination. Records of subsequent tests or monitoring must be maintained for a minimum of 5 years. Records of the control device vendor specifications must be maintained until removal.
(1) Where an owner or operator subject to the provisions of this subpart seeks to demonstrate compliance with § 60.33f(b):
(i) The maximum expected gas generation flow rate as calculated in § 60.36f(a)(1). The owner or operator may use another method to determine the maximum gas generation flow rate, if the method has been approved by the Administrator.
(ii) The density of wells, horizontal collectors, surface collectors, or other gas extraction devices determined using the procedures specified in § 60.40f(a)(1).
(2) Where an owner or operator subject to the provisions of this subpart seeks to demonstrate compliance with § 60.33f(c) through use of an enclosed combustion device other than a boiler or process heater with a design heat input capacity equal to or greater than 44 megawatts:
(i) The average temperature measured at least every 15 minutes and averaged over the same time period of the performance test.
(ii) The percent reduction of NMOC determined as specified in § 60.33f(c)(2) achieved by the control device.
(3) Where an owner or operator subject to the provisions of this subpart seeks to demonstrate compliance with § 60.33f(c)(2)(i) through use of a boiler or process heater of any size: a description of the location at which the collected gas vent stream is introduced into the boiler or process heater over the same time period of the performance testing.
(4) Where an owner or operator subject to the provisions of this subpart seeks to demonstrate compliance with § 60.33f(c)(1) through use of a non-enclosed flare, the flare type (
(5) Where an owner or operator subject to the provisions of this subpart seeks to demonstrate compliance with § 60.33f(c)(3) through use of a landfill gas treatment system:
(i) Bypass records. Records of the flow of landfill gas to, and bypass of, the treatment system.
(ii) Site-specific treatment monitoring plan, to include:
(A) Records of filtration, de-watering, and compression parameters that ensure the treatment system is operating properly for the intended end use of the treated landfill gas.
(B) Monitoring methods, frequencies, and operating ranges for each monitored operating parameter based on manufacturer's recommendations or engineering analysis for the intended end use of the treated landfill gas.
(C) Documentation of the monitoring methods and ranges, along with justification for their use.
(D) Identify who is responsible (by job title) for data collection.
(E) Processes and methods used to collect the necessary data.
(F) Description of the procedures and methods that are used for quality assurance, maintenance, and repair of all continuous monitoring systems.
(c) Except as provided in § 60.38f(d)(2), each owner or operator of a controlled landfill subject to the provisions of this subpart must keep for 5 years up-to-date, readily accessible continuous records of the equipment operating parameters specified to be monitored in § 60.37f as well as up-to-date, readily accessible records for periods of operation during which the parameter boundaries established during the most recent performance test are exceeded.
(1) The following constitute exceedances that must be recorded and reported under § 60.38f:
(i) For enclosed combustors except for boilers and process heaters with design heat input capacity of 44 megawatts (150 million British thermal unit per hour) or greater, all 3-hour periods of operation during which the average temperature was more than 28 °C below the average combustion temperature during the most recent performance test at which compliance with § 60.33f(c) was determined.
(ii) For boilers or process heaters, whenever there is a change in the location at which the vent stream is introduced into the flame zone as required under paragraph (b)(3) of this section.
(2) Each owner or operator subject to the provisions of this subpart must keep up-to-date, readily accessible continuous records of the indication of flow to the control system and the indication of bypass flow or records of monthly inspections of car-seals or lock-and-key configurations used to seal bypass lines, specified under § 60.37f.
(3) Each owner or operator subject to the provisions of this subpart who uses a boiler or process heater with a design heat input capacity of 44 megawatts or greater to comply with § 60.33f(c) must keep an up-to-date, readily accessible record of all periods of operation of the boiler or process heater. (Examples of such records could include records of steam use, fuel use, or monitoring data collected pursuant to other state, local, tribal, or federal regulatory requirements.)
(4) Each owner or operator seeking to comply with the provisions of this subpart by use of a non-enclosed flare must keep up-to-date, readily accessible continuous records of the flame or flare pilot flame monitoring specified under § 60.37f(c), and up-to-date, readily accessible records of all periods of operation in which the flame or flare pilot flame is absent.
(5) Each owner or operator of a landfill seeking to comply with § 60.33f(e) using an active collection system designed in accordance with § 60.33f(b) must keep records of estimates of NMOC emissions for periods when the collection system or control device is not operating.
(d) Except as provided in § 60.38f(d)(2), each owner or operator subject to the provisions of this subpart must keep for the life of the collection system an up-to-date, readily accessible plot map showing each existing and planned collector in the system and providing a unique identification location label on each collector that matches the labeling on the plot map.
(1) Each owner or operator subject to the provisions of this subpart must keep up-to-date, readily accessible records of the installation date and location of all newly installed collectors as specified under § 60.36f(b).
(2) Each owner or operator subject to the provisions of this subpart must keep readily accessible documentation of the nature, date of deposition, amount, and location of asbestos-containing or nondegradable waste excluded from collection as provided in § 60.40f(a)(3)(i) as well as any nonproductive areas excluded from collection as provided in § 60.40f(a)(3)(ii).
(e) Except as provided in § 60.38f(d)(2), each owner or operator subject to the provisions of this subpart must keep for at least 5 years up-to-date, readily accessible records of all collection and control system exceedances of the operational standards in § 60.34f, the reading in the subsequent month whether or not the second reading is an exceedance, and the location of each exceedance.
(f) Landfill owners or operators who convert design capacity from volume to mass or mass to volume to demonstrate that landfill design capacity is less than 2.5 million megagrams or 2.5 million cubic meters, as provided in the definition of “design capacity”, must keep readily accessible, onsite records of the annual recalculation of site-specific density, design capacity, and the supporting documentation. Offsite records may be maintained if they are retrievable within 4 hours. Either paper copy or electronic formats are acceptable.
(g) Landfill owners or operators seeking to demonstrate that site-specific surface methane emissions are below 500 parts per million by conducting surface emission monitoring under the Tier 4 procedures specified in § 60.35f(a)(6) must keep for at least 5 years up-to-date, readily accessible records of all surface emissions monitoring and information related to monitoring instrument calibrations conducted according to sections 8.1.2 and 10 of Method 21 of Appendix A of this part including all of the following items:
(1) Calibration records.
(i) Date of calibration and initials of operator performing the calibration.
(ii) Calibration gas cylinder identification, certification date, and certified concentration.
(iii) Instrument scale(s) used.
(iv) A description of any corrective action taken if the meter readout could not be adjusted to correspond to the calibration gas value.
(v) If an owner or operator makes their own calibration gas, a description of the procedure used.
(2) Timestamp of each surface scan reading, to the nearest minute.
(3) Location of each surface scan reading. The owner or operator must determine the coordinates using an instrument with an accuracy of at least 3 meters. Coordinates must be in decimal degrees with at least five decimal places.
(4) Monitored methane concentration (parts per million) of each reading.
(5) Background methane concentration (parts per million) after each instrument calibration test.
(6) Adjusted methane concentration using most recent calibration (parts per million).
(7) For readings taken at each surface penetration, the unique identification location label matching the label specified in § 60.39f(d).
(h) Except as provided in § 60.38f(d)(2), each owner or operator subject to the provisions of this subpart must keep for at least 5 years up-to-date, readily accessible records of all collection and control system monitoring data for parameters measured in § 60.37f(a)(2) and (3).
(i) Any records required to be maintained by this subpart that are submitted electronically via the EPA's CDX may be maintained in electronic format.
For approval, a State plan must include the specifications for active collection systems in this section.
(a) Each owner or operator seeking to comply with § 60.33f(b) must site active collection wells, horizontal collectors, surface collectors, or other extraction devices at a sufficient density throughout all gas producing areas using the following procedures unless alternative procedures have been approved by the Administrator.
(1) The collection devices within the interior must be certified to achieve comprehensive control of surface gas emissions by a professional engineer. The following issues must be addressed in the design: Depths of refuse, refuse gas generation rates and flow characteristics, cover properties, gas system expandability, leachate and condensate management, accessibility, compatibility with filling operations, integration with closure end use, air intrusion control, corrosion resistance, fill settlement, resistance to the refuse decomposition heat, and ability to isolate individual components or sections for repair or troubleshooting without shutting down entire collection system.
(2) The sufficient density of gas collection devices determined in paragraph (a)(1) of this section must address landfill gas migration issues and augmentation of the collection system through the use of active or passive systems at the landfill perimeter or exterior.
(3) The placement of gas collection devices determined in paragraph (a)(1) of this section must control all gas producing areas, except as provided by paragraphs (a)(3)(i) and (ii) of this section.
(i) Any segregated area of asbestos or nondegradable material may be excluded from collection if documented as provided under § 60.39f(d). The documentation must provide the nature, date of deposition, location and amount of asbestos or nondegradable material deposited in the area, and must be provided to the Administrator upon request.
(ii) Any nonproductive area of the landfill may be excluded from control, provided that the total of all excluded areas can be shown to contribute less than 1 percent of the total amount of NMOC emissions from the landfill. The amount, location, and age of the material must be documented and provided to the Administrator upon request. A separate NMOC emissions estimate must be made for each section proposed for exclusion, and the sum of all such sections must be compared to the NMOC emissions estimate for the entire landfill.
(A) The NMOC emissions from each section proposed for exclusion must be computed using the following equation:
(B) If the owner or operator is proposing to exclude, or cease gas collection and control from, nonproductive physically separated (
(iii) The values for k and CNMOC determined in field testing must be used if field testing has been performed in determining the NMOC emission rate or the radii of influence (the distance from the well center to a point in the landfill where the pressure gradient applied by the blower or compressor approaches zero). If field testing has not been performed, the default values for k, Lo, and CNMOC provided in § 60.35f or the alternative values from § 60.35f must be used. The mass of nondegradable solid waste contained within the given section may be subtracted from the total mass of the section when estimating emissions provided the nature, location, age, and amount of the nondegradable material is documented as provided in paragraph (a)(3)(i) of this section.
(b) Each owner or operator seeking to comply with § 60.33f(b) must construct the gas collection devices using the following equipment or procedures:
(1) The landfill gas extraction components must be constructed of polyvinyl chloride (PVC), high density polyethylene (HDPE) pipe, fiberglass, stainless steel, or other nonporous corrosion resistant material of suitable dimensions to: Convey projected amounts of gases; withstand installation, static, and settlement forces; and withstand planned overburden or traffic loads. The collection system must extend as necessary to comply with emission and migration standards. Collection devices such as wells and horizontal collectors must be perforated to allow gas entry without head loss sufficient to impair performance across the intended extent of control. Perforations must be situated with regard to the need to prevent excessive air infiltration.
(2) Vertical wells must be placed so as not to endanger underlying liners and must address the occurrence of water within the landfill. Holes and trenches constructed for piped wells and horizontal collectors must be of sufficient cross-section so as to allow for their proper construction and completion including, for example, centering of pipes and placement of gravel backfill. Collection devices must be designed so as not to allow indirect short circuiting of air into the cover or refuse into the collection system or gas into the air. Any gravel used around pipe perforations should be of a dimension so as not to penetrate or block perforations.
(3) Collection devices may be connected to the collection header pipes below or above the landfill surface. The connector assembly must include a positive closing throttle valve, any necessary seals and couplings, access couplings and at least one sampling port. The collection devices must be constructed of PVC, HDPE, fiberglass, stainless steel, or other nonporous material of suitable thickness.
(c) Each owner or operator seeking to comply with § 60.33f(c) must convey the landfill gas to a control system in compliance with § 60.33f(c) through the collection header pipe(s). The gas mover equipment must be sized to handle the maximum gas generation flow rate expected over the intended use period of the gas moving equipment using the following procedures:
(1) For existing collection systems, the flow data must be used to project the maximum flow rate. If no flow data exist, the procedures in paragraph (c)(2) of this section must be used.
(2) For new collection systems, the maximum flow rate must be in accordance with § 60.36f(a)(1).
Terms used but not defined in this subpart have the meaning given them in the Clean Air Act and in subparts A and B of this part.
Environmental Protection Agency (EPA).
Supplemental proposal.
The Environmental Protection Agency (EPA) is issuing this supplemental proposal for the Standards of Performance for Municipal Solid Waste (MSW) Landfills to address the nonmethane organic compound (NMOC) emission rate threshold at which an affected MSW landfill must install controls. The EPA is in the process of reviewing the Standards of Performance for MSW Landfills based on changes in the landfills industry since the standards were promulgated in 1996 and issued a proposed rulemaking on July 17, 2014. The EPA's review of the Standards of Performance for MSW Landfills (also referred to as the New Source Performance Standards or NSPS for MSW Landfills) applies to landfills that commenced construction, reconstruction, or modification after July 17, 2014.
This document proposes to achieve additional reductions of landfill gas (LFG) and its components, including methane, through a lower emission threshold at which MSW landfills must install and operate a gas collection and control system (GCCS). This document supplements the proposed July 17, 2014, rulemaking by further lowering, from 40 megagrams per year (Mg/yr) to 34 Mg/yr, the proposed NMOC emissions threshold at which controls would be required. This change to the 2014 proposed threshold is based on additional data we have reviewed that indicate greater potential for reductions in methane emissions from these sources than we originally estimated that can be achieved at reasonable cost. Accordingly, the EPA is proposing to establish the NMOC emission rate threshold for installing a GCCS at 34 Mg/yr and is requesting comment specifically on whether this is appropriate. The EPA is also soliciting comment on the number of facilities that might ultimately become subject to proposed new subpart XXX. The EPA intends to consider the information received in response to this supplemental proposal prior to finalizing revised Standards of Performance for MSW Landfills. The EPA is seeking comment only on the two issues addressed by this supplemental proposal and the supplemental proposal does not otherwise reopen the comment period for the July 17, 2014, proposed rule.
Submit your comments, identified by Docket ID No. EPA-HQ-OAR-2003-0215, to the
Please see section I.C of the Supplementary Information for detailed information on the public hearing.
For information concerning this supplemental proposal, contact Ms. Hillary Ward, Fuels and Incineration Group, Sector Policies and Programs Division, Office of Air Quality Planning and Standards (E143-05), Environmental Protection Agency, Research Triangle Park, NC 27711; telephone number: (919) 541-3154; fax
The purpose of this regulatory action is to propose and take comment on a supplemental change to the proposed Standards of Performance for MSW Landfills resulting from the EPA's ongoing review of the standards under Clean Air Act (CAA) section 111. The EPA is also soliciting comments on the number of facilities that might ultimately become subject to proposed new 40 CFR part 60, subpart XXX.
On July 17, 2014, the EPA proposed a new NSPS subpart (40 CFR part 60, subpart XXX) based on its ongoing review of the MSW Landfills NSPS (40 CFR part 60, subpart WWW) (79 FR 41796) (referred to as “NSPS proposal” in this document). The NSPS proposal is consistent with President Obama's Climate Action Plan and corresponding Methane Strategy. The June 2013 Climate Action Plan directed federal agencies to focus on “assessing current emissions data, addressing data gaps, identifying technologies and best practices for reducing emissions, and identifying existing authorities and incentive-based opportunities to reduce methane emissions.” Methane is a potent greenhouse gas (GHG) that has a warming potential that is 28-36 times greater than carbon dioxide (CO
The proposed new subpart retained the same design capacity size thresholds of 2.5 million cubic meters (m
For the reasons presented below, the EPA is now proposing to establish the NMOC emissions threshold for requiring installation of a GCCS in proposed subpart XXX (of 40 CFR part 60) at 34 Mg/yr, rather than the 40 Mg/yr proposed on July 17, 2014, and is requesting specific comments on whether this is appropriate. The EPA is not proposing to revise the design capacity threshold of 2.5 million m
For the July 17, 2014, NSPS proposal, the EPA estimated the emission reductions and costs associated with 17 new “greenfield” MSW landfills that the EPA projected to commence construction, reconstruction, or modification between 2014 and 2018 and have a design capacity of 2.5 million m
In response to these comments, the EPA consulted with its Regional Offices, as well as state and local authorities, to identify landfills expected to undergo a modification as defined in proposed 40 CFR part 60, subpart XXX within the next 5 years. Based on this information, the EPA estimated the number of existing landfills likely to modify after July 17, 2014, and thereby become subject to proposed subpart XXX. In addition, the EPA made several changes to its underlying dataset and methodology used to analyze the impacts of potential control options, as discussed in the docketed memoranda, “Updated Methodology for Estimating Cost and Emission Impacts of MSW Landfills Regulations. 2015,” and “Updated Methodology for Estimating Testing and Monitoring Costs for the MSW Landfill Regulations. 2015.” The EPA also updated the technical attributes of over 1,200 landfills based on new detailed data reported to 40 CFR part 98, subpart HH of the Greenhouse Gas Reporting Program (GHGRP). A detailed discussion of updates made to the landfill dataset is in the docketed
As a result of the changes to the dataset, the number and characteristics of new landfills that the EPA projected to commence construction, reconstruction, or modification between 2014 and 2018 and modified landfills that are expected to become subject to proposed 40 CFR part 60, subpart XXX have changed.
Using the revised dataset, the EPA re-ran the model using control options similar to the options presented in the proposed NSPS. The EPA's analysis showed that lowering the NMOC emission rate threshold to 34 Mg/yr NMOC would accelerate the schedule for installing a GCCS and also increase the number of landfills required to install controls, thereby achieving additional reductions in emissions of both NMOC and methane.
On July 17, 2014, the EPA proposed an NMOC threshold of 40 Mg/yr and discussed an alternative NMOC emission threshold of 34 Mg/yr in the NSPS proposal and in an Advanced Notice of Proposed Rulemaking (ANPRM) for the Emission Guidelines (for existing landfills). The EPA considered the information received in response to the ANPRM in evaluating whether additional changes beyond those in the proposed revisions for new sources are warranted (79 FR 41772). Commenters on the proposed NSPS for new landfills and the ANPRM for existing landfills expressed mixed reactions to a lower NMOC emission rate threshold. Several nongovernmental organizations and a local government entity supported a reduction in the NMOC emissions threshold. One state agency provided examples of existing landfills controlling emissions in its state with estimated NMOC emission rates as low as 8.1 Mg/yr.
In contrast, several commenters were concerned with the financial and technical implications of lowering the threshold, including whether landfills were financially prepared to install controls at an earlier time, or whether landfills would lose potential carbon credit revenue from voluntary projects. Another state agency expressed concerns that landfills in arid areas would have difficulty continuously operating a flare at landfills with lower quality gas that emit between 40 and 50 Mg/yr.
Table 1 of this document shows the emission reductions and costs for control options, when using a 7 percent discount rate, in year 2025 at new and modified landfills. At the baseline size and emissions thresholds (
The incremental emission reductions for an NMOC emission rate of 40 Mg/yr would be 300 Mg/yr NMOC and 44,400 Mg/yr methane (1.1 million metric tons of CO
The only categories of benefits monetized for this supplemental proposal are methane-related climate impacts and minor secondary CO
A similar metric, the social cost of CO
The SC-CH
The methodology used to calculate methane climate benefits is discussed in detail in Section 4.2 of the RIA. Applying the approach discussed in the RIA to the methane reductions estimated for this supplemental proposal, the 2025 methane benefits of this supplemental proposal vary by discount rate and range from $36 million (2012$) to $210 million (2012$); the mean SC-CH
Consistent with the Methane Strategy that was developed as part of the President's Climate Action Plan, the EPA considered control options to achieve additional reductions of methane and NMOC for new landfills. The Climate Action Plan directed the EPA and five other federal agencies to develop a comprehensive interagency strategy to reduce methane emissions. Specifically, the federal agencies were instructed to focus on “assessing current emissions data, addressing data gaps, identifying technologies and best practices for reducing emissions and identifying existing authorities and incentive-based opportunities to reduce methane emissions.” With respect to landfills, the Methane Strategy directs the agency to build upon progress to date through updates to the EPA's rules for reducing emissions from new, modified, and reconstructed landfills. Based on the Climate Action Plan and Methane Strategy, the revised analysis described above, and consideration of comments received on the proposed NSPS and ANPRM, the EPA is proposing to lower the NMOC emission rate threshold to 34 Mg/yr for new (new, modified, and reconstructed) sources subject to proposed 40 CFR part 60, subpart XXX. The EPA is not proposing changes to the design capacity thresholds.
The EPA believes a level of 34 Mg/yr NMOC is achievable for new and modified landfills. Greenfield and modified landfill owners or operators are expected to employ the latest technology and practices to minimize emissions and will have the time to consider the latest technology and practices as they plan the construction of a new landfill or construction of a new cell of a modified landfill. Because the emission threshold level of 34 Mg/yr is more stringent than the level the EPA proposed on July 17, 2014, and the impacts associated with this proposed level of control have a different basis than those outlined in the original proposal, the EPA is soliciting comments on the revised analysis of the proposed NSPS in this supplemental proposal. The EPA is also soliciting comments and data that would help identify landfills that are expected to modify, as defined in the proposed NSPS, during the next 5 years (2014-2018). Comments on an NMOC emission threshold of 34 Mg/yr and comments or data on landfills modifying in the next 5 years should be submitted to Docket ID No. EPA-HQ-OAR-2003-0215. The EPA is not otherwise reopening proposed 40 CFR part 60, subpart XXX for additional comment.
Please contact Ms. Aimee St. Clair at (919) 541-1063 or at
If a hearing is held, it will provide interested parties the opportunity to present data, views or arguments concerning the proposed action. The
The EPA may ask clarifying questions during the oral presentations, but will not respond to the presentations at that time. Written statements and supporting information submitted during the comment period will be considered with the same weight as oral comments and supporting information presented at the public hearing. Commenters should notify Ms. St. Clair if they will need specific equipment, or if there are other special needs related to providing comments at the hearing. Verbatim transcripts of the hearing and written statements will be included in the docket for the rulemaking. The EPA will make every effort to follow the schedule as closely as possible on the day of the hearing; however, please plan for the hearing to run either ahead of schedule or behind schedule. A public hearing will not be held unless requested. Please contact Ms. Aimee St. Clair at (919) 541-1063 or at
Additional information about these statues and Executive Orders can be found at
This action supplements a prior proposed action that was determined to be an economically significant regulatory action that was submitted to the Office of Management and Budget (OMB) for review. Any changes made in response to OMB recommendations have been documented in the docket. The EPA prepared an analysis of the potential costs and benefits associated with this action. This analysis, “Regulatory Impact Analysis for the Proposed Revisions to the Emission Guidelines for Existing Sources and Supplemental Proposed New Source Performance Standards in the Municipal Solid Waste Landfills Sector” is available in the docket.
The information collection requirements in this supplemental proposal have been submitted for approval to OMB under the PRA. The Information Collection Request (ICR) document that the EPA prepared for this supplemental proposal has been assigned EPA ICR number 2498.02. You can find a copy of the ICR in the docket for this rule, and it is briefly summarized here.
The information required to be collected is necessary to identify the regulated entities subject to the proposed NSPS and to ensure their compliance with the proposed NSPS and this supplemental proposal. The recordkeeping and reporting requirements are mandatory and are being established under authority of CAA section 114 (42 U.S.C. 7414). All information other than emissions data submitted as part of a report to the agency for which a claim of confidentiality is made will be safeguarded according to CAA section 114(c) and the EPA's implementing regulations at 40 CFR part 2, subpart B.
The information collection requirements in the proposed NSPS (79 FR 41828, July 17, 2014) were submitted for approval to OMB under the PRA. The ICR document that the EPA prepared was assigned EPA ICR number 2498.01. Since the NSPS review was proposed on July 17, 2014, the EPA updated the number of existing landfills likely to modify after July 17, 2014, and, thus, become subject to proposed 40 CFR part 60, subpart XXX, as discussed in this preamble. The supplemental proposal to lower the emission threshold for new and modified sources affects the burden estimates the EPA presented in EPA ICR number 2498.01. As a result, the EPA updated the EPA ICR number 2498.01 and re-submitted it to OMB for approval as EPA ICR 2498.02 to reflect the estimated number of respondents and a lower NMOC emission rate. A copy of the ICR is in Docket ID No. EPA-HQ-OAR-2003-0215, and it is briefly summarized here.
An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB control number. The OMB control numbers for the EPA's regulations in 40 CFR are listed in 40 CFR part 9.
Submit your comments on the agency's need for this information, the accuracy of the provided burden estimates and any suggested methods for minimizing respondent burden to the EPA using the docket identified at the beginning of this rule. You may also send your ICR-related comments to OMB's Office of Information and Regulatory Affairs via email to
I certify that this action will not have a significant economic impact on a substantial number of small entities under the RFA. The small entities subject to the requirements of the
Although not required by the RFA to convene a Small Business Advocacy Review (SBAR) Panel because the EPA has now determined that the proposed NSPS would not have a significant economic impact on a substantial number of small entities, the EPA originally convened a panel to obtain advice and recommendations from small entity representatives potentially subject to this rule's requirements. A copy of the Summary of Small Entity Outreach is included in Docket ID No. EPA-HQ-OAR-2003-0215.
This action does not contain any unfunded mandate of $100 million or more as described in UMRA, 2 U.S.C. 1531-1538. This supplemental NSPS proposal applies to landfills that commenced construction, reconstruction, or modification after July 17, 2014. Impacts resulting from the proposed NSPS are far below the applicable threshold. Thus, the proposed NSPS is not subject to the requirements of sections 202 or 205 of the UMRA. However, in developing the proposed NSPS, the EPA consulted with small governments pursuant to a plan established under section 203 of the UMRA to address impacts of regulatory requirements in the rule that might significantly or uniquely affect small governments. The EPA held meetings as discussed in section II.E of this preamble under Federalism consultations.
The EPA has concluded that the supplemental proposal for the NSPS does not have Federalism implications. The proposed NSPS 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, as specified in Executive Order 13132. The supplemental proposal will not have impacts of $25 million or more in any one year. Thus, Executive Order 13132 does not apply to the supplemental proposal.
Although section 6 of Executive Order 13132 does not apply to the supplemental NSPS proposal, the EPA consulted with state and local officials and representatives of state and local governments early in the process of developing the proposed rules for MSW landfills (both the NSPS and Emission Guidelines) to permit them to have meaningful and timely input into its development.
The EPA conducted a Federalism Consultation Outreach Meeting on September 10, 2013. Due to interest in that meeting, additional outreach meetings were held on November 7, 2013, and November 14, 2013. Participants included the National Governors' Association, the National Conference of State Legislatures, the Council of State Governments, the National League of Cities, the U.S. Conference of Mayors, the National Association of Counties, the International City/County Management Association, the National Association of Towns and Townships, the County Executives of America, the Environmental Council of States, National Association of Clean Air Agencies, Association of State and Territorial Solid Waste Management Officials, environmental agency representatives from 43 states, and approximately 60 representatives from city and county governments. The comment period for the outreach meetings related to the NSPS proposal was extended to allow sufficient time for interested parties to review briefing materials and provide comments. Concerns raised during the consultations include: implementation concerns associated with shortening of gas collection system installation and/or expansion timeframes, concerns regarding significant lowering of the design capacity or emission thresholds, the need for clarifications associated with wellhead operating parameters and the need for consistent, clear and rigorous surface monitoring requirements.
The supplemental proposal does not have tribal implications, as specified in Executive Order 13175 (65 FR 67249, November 9, 2000). Based on methodology used to predict future landfills as outlined in the docketed memorandum “Summary of Landfill Dataset Used in the Cost and Emission Reduction Analysis of Landfills Regulations. 2014,” future tribal landfills are not anticipated to be large enough to become subject to the proposed NSPS or this supplemental proposal. Thus, Executive Order 13175 does not apply to this action. The EPA specifically solicits comment on this action from tribal officials.
The EPA interprets Executive Order 13045 as applying only to those regulatory actions that concern environmental health or safety risks that the EPA has reason to believe may disproportionately affect children, per the definition of “covered regulatory action” in section 2-202 of the Executive Order. The supplemental NSPS proposal is not subject to Executive Order 13045 because it does not concern an environmental health risk or safety risk. We also note that the methane and NMOC reductions expected from the proposed NSPS will have positive health effects, including for children.
This action is not a “significant energy action” because it is not likely to have a significant adverse effect on the supply, distribution, or use of energy. Further, we have concluded that the proposed NSPS and supplemental NSPS proposal are not likely to have any adverse energy effects because the energy demanded to operate these control systems will be offset by additional energy supply from LFG energy projects.
This supplemental NSPS proposal does not involve technical standards, however, the NSPS proposed on July 17, 2014 involves technical standards. For the proposed NSPS, the EPA has proposed to use EPA Methods 2E, 3, 3A, 3C, 21, 25, and 25C of 40 CFR part 60, appendix A. While the EPA identified nine voluntary consensus standards (VCS) as being potentially applicable (ANSI/ASME PTC 19-10-1981 Part 10, ASTM D3154-00 (2006), ASME B133.9-1994 (2001), ISO 10396:1993 (2007), ISO 12039:2001, ASTM D5835-95 (2007), ASTM D6522-00 (2005), CAN/CSA Z223.2-M86 (1999), ISO 14965:2000(E)), the agency decided not to use these methods. The EPA determined that the nine candidate VCS identified for measuring emissions of pollutants or their surrogates subject to emission standards in the rule would not be practical due to lack of equivalency, documentation, validation data, and other important technical and policy considerations. The EPA's review, including review comments for these nine methods, is documented in the memorandum, “Voluntary Consensus Standard Results for Standards of Performance for Municipal Solid Waste Landfills 40 CFR part 60, subpart XXX” in the Docket ID No. EPA-HQ-OAR-2003-0215.
The EPA believes the human health or environmental risk addressed by the proposed NSPS and this supplemental proposal will not have potential disproportionately high and adverse human health or environmental effects on minority, low-income, or indigenous populations because the proposed NSPS and this supplemental proposal would reduce emissions of LFG, which contains both NMOC and methane. These avoided emissions will improve air quality and reduce public health and welfare effects associated with exposure to LFG emissions. Regarding the NSPS proposal and this supplemental proposal, the EPA has concluded that it is not practicable to determine whether there would be disproportionately high and adverse human health or environmental effects on minority, low income, or indigenous populations from the proposed NSPS and supplemental proposal because it is unknown where new or modified facilities will be located. The demographic analysis results and the details concerning their development are presented in the April 22, 2014 document titled, “2014 Environmental Justice Screening Report for Municipal Solid Waste Landfills,” a copy of which is available in the docket (Docket ID No. EPA-HQ-OAR-2003-0215).
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 |