Air Quality Control, Reporting, and Compliance, 19717-19816 [2016-06310]

Download as PDF Vol. 81 Tuesday, No. 65 April 5, 2016 Part II Department of the Interior asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Bureau of Ocean Energy Management 30 CFR Part 550 Air Quality Control, Reporting, and Compliance; Proposed Rules VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00001 Fmt 4717 Sfmt 4717 E:\FR\FM\05APP2.SGM 05APP2 19718 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules DEPARTMENT OF THE INTERIOR Bureau of Ocean Energy Management 30 CFR Part 550 [Docket ID: BOEM–2013–0081] RIN 1010–AD82 Air Quality Control, Reporting, and Compliance Bureau of Ocean Energy Management (BOEM), Interior. ACTION: Proposed rule. AGENCY: This proposed rule would amend existing BOEM regulations related to air quality measurement, evaluation, and control with respect to oil, gas, and sulphur operations on the Outer Continental Shelf (OCS) of the United States (U.S.), in the Central and Western Gulf of Mexico (GOM) and the area offshore the North Slope Borough of the State of Alaska, as part of the BOEM approval process for offshore oil and gas exploration and development plans, right-of-use and easement (RUE), pipeline rights-of-way (ROW), and lease term pipeline applications. The proposed rule would: (1) Fulfill BOEM’s statutory responsibility under section 5(a)(8) of Outer Continental Shelf Lands Act (OCSLA) by addressing all relevant criteria and major precursor air pollutants and by cross-referencing BOEM standards and benchmarks for those pollutants to those of the United States Environmental Protection Agency (USEPA); (2) change the manner in which lessees would evaluate and model vessel emissions attributed to OCS facilities; (3) change the methods for measuring and evaluating air emissions including measuring their impacts over State submerged lands; (4) provide a process by which exemption thresholds are established and updated; (5) change the circumstances when emission reduction measure(s) (ERM), including Best Available Control Technology (BACT), are required, and establish new criteria for the application of ERM; (6) formalize requirements for the consolidation of emissions from multiple facilities; (7) consistent with BOEM’s existing regulatory authority, articulate a schedule and requirements for ensuring that all plans, including those previously approved, will remain compliant on an ongoing basis with these updated regulations; and (8) include an air quality component in the submission of RUE, ROW, and lease term pipeline applications. Key policy changes include the following: (1) Aligning the list of pollutants that are subject to an air asabaliauskas on DSK3SPTVN1PROD with PROPOSALS SUMMARY: VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 quality review with the current National Ambient Air Quality Standards (NAAQS) and cross-referencing the ambient air quality standards and benchmarks (AAQSB) for those pollutants to those of the USEPA; (2) formalizing the concept and application of the term ‘‘attributed emissions;’’ (3) changing the locations where air emissions will be measured and evaluated; and (4) modifying the process by which exemption thresholds are established and updated. This rulemaking would be the first major rewrite of the OCS air quality regulations in 35 years. DATES: Submit comments on the substance of this rulemaking by June 6, 2016. Send your comments on the substance of the proposed rule to the Department as directed in the ADDRESSES section below. Submit comments on the information collection (IC) burden in this rulemaking to the Office of Management and Budget (OMB) by May 5, 2016. ADDRESSES: You may submit comments, identified by the number 1010–AD82, by any of the following methods: • Federal rulemaking portal: https:// www.regulations.gov. Follow the instruction for submitting comments. • Mail: Department of the Interior, Bureau of Ocean Energy Management, Office of Policy, Regulation, and Analysis, Attention: Peter Meffert, 45600 Woodland Road, Sterling, Virginia 20166. • Hand delivery: Front Desk, Department of the Interior, Bureau of Ocean Energy Management, Office of Policy, Regulation, and Analysis, Attention: Peter Meffert, 45600 Woodland Road, Sterling, Virginia 20166. Please include your name, return address and phone number and/or email address, so we can contact you if we have questions regarding your submission. Send comments on the IC of this rule to: Interior Desk Officer 1010–AD82, Office of Management and Budget; 202– 395–5806 (fax); email OIRA_ Submission@eop.gov. Please also send a copy to BOEM at 45600 Woodland Road, Sterling, VA 20166. Public Availability of Comments: BOEM does not consider anonymous comments; please include your name and address as part of your submittal. Before including your name, address, phone number, email address, or other personal identifying information in your comment, you should be aware your entire comment—including your personal identifying information—may be made publicly available at any time. PO 00000 Frm 00002 Fmt 4701 Sfmt 4702 While you can ask us in your comment to withhold your personal identifying information from public review, we cannot guarantee we will be able to do so. FOR FURTHER INFORMATION CONTACT: Peter Meffert, Bureau of Ocean Energy Management, Office of Policy, Regulation, and Analysis, at Peter.Meffert@boem.gov or mail to 45600 Woodland Road, Sterling, Virginia 20166; or call (703) 787–1610. SUPPLEMENTARY INFORMATION: Table of Contents I. General Information A. What should I consider as I prepare my comments for BOEM? 1. Submitting Confidential Business Information (CBI) 2. Tips for Preparing Your Comments B. Availability of Related Information C. Abbreviations of Terms and Acronyms II. Executive Summary III. Background A. Statutory Authority B. Current Air Quality Framework—Air Quality Regulatory Program C. Air Quality Regulatory Program Data Requirements 1. Projected Emissions 2. Maximum Potential Emissions 3. Processes, Equipment, Fuels, and Combustibles 4. Distance to Shore 5. Emission Reduction Measure(s) (ERM) 6. Non-Exempt Drilling Units 7. Documentation D. Proposed Analytical Approach 1. Flowchart 2. Exemption Threshold Analysis 3. Modeling Analysis 4. Controls for Short-Term Facilities 5. Controls for Long-Term Facilities 6. Protection of Exceptional Natural Resources 7. Primary and Secondary National Ambient Air Quality Standards (NAAQS) Evaluation 8. Intersection With the National Environmental Policy Act (NEPA) 9. Additional Environmental Review E. Conclusion IV. Summary of Key Changes A. Air Pollution Emissions Standards B. Attributed Emissions 1. Emissions From Stationary Sources 2. Emissions From Mobile Support Craft 3. Determination of Attributed Emissions 4. Exclusion of Aircraft and Onshore Emissions Sources C. Points of Measurement 1. Point-of-Origin Measurement 2. State Seaward Boundary (SSB) 3. Point-of-Impact Measurement 4. Ambient Air Quality Monitoring D. Emission Exemption Threshold(s) (EETs) E. Emission Reduction Measure(s) (ERM) 1. Emissions Credits and Offsets 2. Applicability of Best Available Control Technology (BACT) Upon an Exceedance of the Significant Impact Levels (SILs) 3. ERM Evaluation Criteria E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules 4. Nitrogen Oxides (NOX) Waiver and Volatile Organic Compounds (VOC) Waiver F. Consolidation of Emissions From Multiple Facilities G. Ongoing Monitoring and Review of Projected Emissions 1. Recordkeeping and Measurement Criteria H. Structure of the Proposed Rule 1. Potential Monitoring Alternative 2. Plan Resubmittals I. Gulf-Wide Offshore Activities Data System (GOADS) J. Prevention of Significant Deterioration V. Section-by-Section Analysis of the Proposed Rule A. 30 Code of Federal Regulations (CFR) Part 550, Subpart A B. 30 CFR Part 550, Subpart B C. 30 CFR Part 550, Subpart C D. 30 CFR Part 550, Subpart J VI. Interagency, Tribal, and Public Outreach VII. Legal and Regulatory Analyses A. Statutes 1. National Environmental Policy Act (NEPA) of 1969 2. Paperwork Reduction Act (PRA) of 1995 3. Regulatory Flexibility Act of 1980 4. Small Business Regulatory Enforcement Fairness Act of 1996 5. Unfunded Mandates Reform Act of 1995 B. Executive Orders (E.O.) and Presidential Memorandum 1. Governmental Actions and Interference With Constitutionally Protected Property Rights (E.O. 12630) March 15, 1988 2. Regulatory Planning and Review (E.O. 12866) October 4, 1993 3. Civil Justice Reform (E.O. 12988) February 7, 1996 4. Protection of Children From Environmental Health and Safety Risks (E.O. 13045) April 21, 1997 5. Federalism (E.O. 13132) August 10, 1999 6. Consultation and Coordination With Indian Tribal Governments (E.O. 13175) November 6, 2000 7. Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution or Use (E.O. 13211) May 18, 2001 8. Enhancing Coordination of National Efforts in the Arctic (E.O. 13689) January 21, 2015 9. Improving Regulation and Regulatory Review (E.O. 13563) January 18, 2011 10. Presidential Memorandum of June 1, 1998 on Plain Language in Government Writing I. General Information asabaliauskas on DSK3SPTVN1PROD with PROPOSALS A. What should I consider as I prepare my comments for BOEM? 1. Submitting Confidential Business Information (CBI) Do not submit CBI or proprietary information to BOEM through www.regulations.gov or email. Clearly mark the part or all of the information you claim to be CBI. For CBI information in a disk or CD ROM you mail to BOEM, mark the outside of the disk or CD ROM as CBI and then VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 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, submit a copy of the comment that does not contain the information claimed as CBI for inclusion in the public docket. Information so marked will not be disclosed. Any CD or data submitted to BOEM must be virus-free and usable, as submitted. BOEM will not attempt to correct, fix or amend any CD or other electronic media that is not readily accessible. 2. Tips for Preparing Your Comments When submitting comments, remember to: • Identify the rulemaking by docket number and other identifying information (subject heading, Federal Register (FR) date and page number). • Organize Comments—When your comments respond to specific provisions, organize your comments by referencing the relevant CFR part or section number in the proposed rule. • Explain why you agree or disagree, and suggest alternatives, and/or substitute language for your requested changes. • Describe any assumptions and provide any technical information and/ or data you used. • Provide specific examples to illustrate your concerns. • Explain your views as clearly as possible, avoiding the use of profanity or personal threats. • Make sure to submit your comments by the comment period deadline identified. B. Availability of Related Information A number of documents relevant to this air quality rulemaking, including past and planned environmental studies and analysis, are available on the BOEM Web site at www.BOEM.gov. In addition, the economic and environmental analyses associated with this rulemaking are available for inspection and copying in the BOEM docket for this rulemaking, as identified above and are also available at www.BOEM.gov. C. Abbreviations of Terms and Acronyms The following are abbreviations of terms used in the preamble. AAI Ambient Air Increment AAQSB Ambient Air Quality Standards and Benchmarks AEDT Aviation Environmental Design Tool (Federal Aviation Administration) AQCR Air Quality Control Region AQRP Air Quality Regulatory Program PO 00000 Frm 00003 Fmt 4701 Sfmt 4702 19719 AQRV Air Quality Related Value AQS Air Quality Subsystem (USEPA) BACT Best Available Control Technology BC Black Carbon (component of PM2.5) BLM Bureau of Land Management BOEM Bureau of Ocean Energy Management BSEE Bureau of Safety and Environmental Enforcement Btu IT British Thermal Unit International Tables CAA Clean Air Act, as amended CAMX Comprehensive Air Quality Model with Extensions CBI Confidential Business Information CEO Chief Environmental Officer (BOEM) CFR Code of Federal Regulations CH4 Methane CMAQ Community Multi-scale Air Quality Model (USEPA) CO Carbon Monoxide CO2 Carbon Dioxide CP Criteria Pollutant CSU Column-Stabilized Units DOCD Development Operations Coordination Document DOI Department of the Interior DPP Development and Production Plan EC Elemental Carbon ECE Emission Control Efficiency EET Emission Exemption Threshold(s) EEZ Exclusive Economic Zone EIS Environmental Impact Statement E.O. Executive Order EP Exploration Plan ERM Emission Reduction Measure(s) FAA Federal Aviation Administration FIRE Factor Information Retrieval System FLM Federal Land Manager (Bureau of Land Management (BLM), United States Fish and Wildlife Service (FWS), National Park Service (NPS), and United States Department of Agriculture Forest Service (USFS)) FPS Floating Production System FPSO Floating Production, Storage, and Offloading vessel FR Federal Register FWS Fish and Wildlife Service (DOI) GAO Government Accountability Office G&G Geological and Geophysical GHG Greenhouse Gas GOADS Gulf-wide Offshore Activities Data System GOM Gulf of Mexico H2S Hydrogen Sulfide hp Horsepower hpm Mechanical Horsepower IC Information Collection IRFA Initial Regulatory Flexibility Analysis IRIA Initial Regulatory Impact Analysis kW kilowatt MACI Maximum Allowable Concentration Increase MARPOL International Convention for the Prevention of Pollution from Ships MODU Mobile Offshore Drilling Unit MSC Mobile Support Craft NAAQS National Ambient Air Quality Standards NEI National Emissions Inventory (USEPA) NEPA National Environmental Policy Act of 1969 NESHAP National Emissions Standards for Hazardous Air Pollutants NH3 Ammonia E:\FR\FM\05APP2.SGM 05APP2 19720 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS NO2 Nitrogen Dioxide NOX Nitrogen Oxides N2O Nitrous Oxide NPS National Park Service (DOI) NSPS New Source Performance Standards NSR New Source Review (USEPA) NTC NOX Technical Code NTL Notice to Lessees O3 Ozone OCS Outer Continental Shelf OCSLA Outer Continental Shelf Lands Act of 1953, as amended OIRA Office of Information and Regulatory Affairs (Office of Management and Budget) OMB Office of Management and Budget (Executive Office of the President) ONRR Office of Natural Resources Revenue (DOI) OSV Offshore Supply Vessel Pb Lead PEMS Parametric Emissions Monitoring Systems PM Particulate Matter PM2.5 Fine Particulate Matter, 2.5 micrometers in diameter or less PM10 Particulate Matter, 10 micrometers in diameter or less PRA Paperwork Reduction Act of 1995 PSD Prevention of Significant Deterioration PTE Potential to Emit Pub. L. Public Law RIA Regulatory Impact Analysis ROV Remotely Operated Vehicle ROW Right-of-Way rpm Revolutions per minute RUE Right of-Use and Easement SBA Small Business Administration SCC Source Classification Codes SIL Significant Impact Level SMOKE Sparse Matrix Operator Kernel Emissions SO2 Sulphur Dioxide SOB Statement of Basis SOX Sulphur Oxides SIP State Implementation Plan SSB State seaward boundary TAS Treatment as State TIMS-Web Technical Information Management System Web-based Application TIP Tribal Implementation Plan TLP Tension-Leg Platforms tpy Tons per year TSP Total Suspended Particulates U.S. United States USCG United States Coast Guard U.S.C. United States Code USEPA United States Environmental Protection Agency USGS United States Geological Survey VOC Volatile Organic Compound mg/m3 Micrograms per cubic meter II. Executive Summary The Outer Continental Shelf Lands Act (OCSLA) requires the Department of the Interior (DOI) to promulgate regulations for compliance with the National Ambient Air Quality Standards (NAAQS) pursuant to the Clean Air Act (CAA) (42 U.S.C. 7401 et seq.), to the extent that activities approved under OCSLA significantly affect the air quality of any State (43 U.S.C. 1334(a)(8)). The U.S. Geological Survey VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 (USGS), a BOEM predecessor agency, prepared the first air quality regulations under OCSLA, which were promulgated by the Secretary of the Interior in 1980 (45 FR 15128, March 7, 1980). The current version of these regulations is contained in 30 CFR part 550 (‘‘Oil, Gas and Sulphur Operations in the Outer Continental Shelf’’) subparts A (‘‘General’’), B (‘‘Plans and Information’’), and C (‘‘Pollution Prevention and Control’’). These regulations require: (1) The submission of information on projected air emissions from offshore oil and gas exploration or development activities with a proposed plan for exploration (i.e., an exploration plan (EP)) or development (i.e., a Development and Production Plan (DPP) or a Development Operations Coordination Document (DOCD); (2) the application of various emission exemption thresholds to determine whether air quality impacts would be presumed de minimis and, therefore, not require further BOEM review under subpart C or whether the impacts would exceed the threshold and require further review under subpart C; (3) the modeling of projected emissions when a facility’s projected emissions exceed the exemption thresholds and would therefore potentially cause air quality impacts to a State; 1 and, (4) the control 1 In the 1990 Clean Air Act Amendments, Congress added two provisions authorizing Federally-recognized Indian tribes to be treated like States under the CAA. Congress added section 301(d) that authorizes the Administrator of the USEPA ‘‘to treat Indian tribes as States.’’ In implementing this provision, the USEPA published proposed rule entitled ‘‘the Tribal Clean Air Act Authority’’ to implement this provision of the Act. In its proposed rule (63 FR 7271, Feb. 12, 1998), the USEPA stated ‘‘[The] Regulations in this part identify those provisions of the Clean Air Act for which Indian tribes are or may be treated in the same manner as States. In general, these regulations authorize eligible tribes to have the same rights and responsibilities as States under the Clean Air Act and authorize EPA approval of tribal air quality programs meeting the applicable minimum requirements under the Act.’’ Furthermore, in its ‘‘EPA Statement of Policy on Consultation and Coordination with Indian Tribes,’’ dated May 4, 2011, on p. 3 in the section entitled Guiding Principles, the USEPA states: ‘‘EPA recognizes and works directly with Federally-recognized tribes as sovereign entities with primary authority and responsibility for each tribe’s land and membership, and not as political subdivisions of states or other governmental units.’’ Just as States establish State Implementation Plans (SIPs) to comply with CAA/ USEPA requirements, the tribes can establish Tribal Implementation Plans (TIPs) to regulate the air quality over tribal lands (which are then outside the general jurisdiction of the State SIP). In addition, for those tribes that have been granted ‘‘treatment as State’’ (TAS) status (i.e., providing for Indian tribes to play essentially the same role in Indian country that states do within State lands for purposes of air quality management), BOEM will allow such a tribe to appeal the approval of a plan, in a manner similar to that accorded to States. For this reason, BOEM has proposed to expand the PO 00000 Frm 00004 Fmt 4701 Sfmt 4702 of an emissions source proposed for any facility that would cause or contribute to an exceedance of the AAQSB. BOEM is proposing to revise and replace its air quality regulations with a new set of regulations that reflect a number of policy changes with respect to the existing air quality regulatory program (AQRP (30 CFR 550 subpart C)). While the existing underlying framework would remain the same in a number of key aspects, the proposed rule would change in significant ways the manner in which BOEM regulates emissions from certain sources on the OCS. The most significant changes in the proposed rule relate to: (1) Fulfilling BOEM’s statutory responsibility under section 5(a)(8) of OCSLA by addressing all relevant criteria and major precursor air pollutants and by cross-referencing the AAQSB for those pollutants to those of the USEPA; (2) formalizing the concept and application of the term ‘‘attributed emissions;’’ (3) changing the methods for determining the locations from which air emissions will be measured and evaluated; (4) modifying the process by which emission exemption thresholds (EETs) are established and updated; (5) changing the circumstances when ERM, including Best Available Control Technology (BACT), are required, and establishing new criteria for the application of ERM; (6) revising the boundary at which BOEM determines air quality compliance to the State seaward boundary (SSB), rather than the coastline; (7) formalizing requirements for the consolidation of emissions from multiple facilities; (8) consistent with BOEM’s existing regulatory authority, articulating a schedule for ensuring that plans, including previously approved plans, will be compliant with these updated regulations; (9) adding an air quality component to the submission of RUE, ROW, and lease term pipeline applications; (10) an expanded use of offsets as an alternative in circumstances where BACT was previously required; and (11) the addition of a new requirement for all plans to be reviewed at least every 10 years, to ensure ongoing compliance with the NAAQS, as amended from time to time. BOEM is proposing to amend the current regulations to provide a mechanism by which the regulations remain up-to-date in the future, particularly when the USEPA changes an applicable AAQSB; to reflect the analysis of impacts under its air quality rules to include potential impacts to Federally-recognized Indian tribes having either TAS status or an approved TIP. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS recent statutory expansion of BOEM’s air quality jurisdiction (42 U.S.C. 7627, as amended by Pub. L. 112–74); to improve the clarity of existing regulatory provisions; to account for technological advances in air quality measurement, evaluation, and reporting that have occurred since the current regulations were promulgated; and to reflect industry practices and procedures that have evolved since 1980. BOEM is proposing to define a number of additional key terms, to clarify the objectives and procedures associated with the AQRP, and to reorganize a number of existing provisions in its regulations. The proposed rule would consolidate all the existing data collection and information requirements in a single section dedicated to air quality. The pertinent provisions of BOEM’s regulations related to air quality would be either substantially updated or entirely replaced. The proposed rule would make a number of changes to the existing requirements associated with reporting, tracking, modeling, and monitoring the air emissions from stationary facilities operating on the OCS and emissions from associated non-stationary sources, including vessels and vehicles, and aircraft traversing above the OCS or over State submerged lands 2 that operate in support of such facilities. Since BOEM’s current air quality regulations were published in 1980, the USEPA has revised the NAAQS to include additional criteria pollutants (i.e., to include Fine Particulate Matter, 2.5 micrometers in diameter or less (PM2.5)), standards with a wider range of averaging times and statistical forms.3 There are two types of NAAQS: Primary NAAQS, which are intended to protect public health with an adequate margin of safety; and secondary NAAQS, which are focused on protecting public welfare. This proposed rule would enhance the process by which operators of OCS facilities determine whether their proposed exploratory or developmental activities could cause or contribute to a significant adverse impact to the air 2 State submerged lands are the part of each State’s territory that extends from the shoreline up to the point of federal jurisdiction (typically three miles from shore, but in some cases extending up to nine miles from shore). In contrast, the offshore lands under federal jurisdiction are referred to as the Outer Continental Shelf (OCS). 3 In general, air quality standards are based on the concentration of a given pollutant at a given location averaged over a particular length of time, called the averaging time, evaluated in combination with some statistical parameter, which is referred to as the statistical form of the standard. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 quality of any State. It would define the circumstances under which BOEM would require lessees and operators 4 to control their air emissions in order to meet the USEPA’s air pollution controlrelated standards for criteria air pollutants (i.e., pollutants for which there are NAAQS) and major precursor air pollutants. The proposed rule would incorporate by reference USEPA’s Significant Impact Levels (SILs), Ambient Air Increments (AAIs), and the primary and secondary NAAQS. It would also make a number of changes to ensure that certain provisions within BOEM’s rules are automatically updated whenever the USEPA updates its NAAQS, SILs and AAIs. Because the USEPA’s current NAAQS include standards for both annual and short-term averaging times, the proposed rule would also provide for the collection, evaluation, and consideration of data with respect to the long-term and short-term exposure to air pollution originating from the OCS. Under current BOEM regulations, most of the effects that are evaluated relate to an annual exposure to a certain level of pollution. Short-term averaging times measure something different, namely the potential impact of a short-term exposure to the same pollutant, where the level of pollution is much greater. In some cases, the long-term exposure to low levels of pollution may be harmful; in other cases, the short-term exposure to high levels of pollution may also be harmful. Because the proposed rule would evaluate different levels of exposure over different time periods, the proposed rule would more accurately determine whether any OCS operations would have the potential to cause an adverse effect to a State’s air quality. The proposed rule would require the modeling of emissions over any averaging time that the USEPA has determined would be relevant whenever the projected annual emissions of a given pollutant exceed the EETs. This change would, therefore, enable BOEM to better ensure compliance with all the NAAQS. This change is of particular relevance in the case of nitrogen oxides (NOX) because that air pollutant is the one for which the annual exemption threshold is most often exceeded. In order to ensure ongoing compliance with the NAAQS referenced in OCSLA, the proposed rule would also provide for the collection of additional information on approved activities 4 Although the rule refers to lessees or operators, the provisions of the proposed rule would also apply to right-of-way holders, right-of-use and easement holders, lease-term pipeline applicants and any other party or parties that may be required to submit a plan to BOEM for review and approval. PO 00000 Frm 00005 Fmt 4701 Sfmt 4702 19721 described in any initial, revised, modified, resubmitted, or supplemental EP, DPP, or DOCD, or application for a RUE, pipeline ROW, or lease term pipeline (hereinafter referred to by the general term ‘‘plan’’), in order to verify the information reported in the plan. As is the case with the current BOEM regulations, the proposed rule would establish emissions exemptions thresholds. The proposed rule would continue to require facilities whose projected emissions of criteria and major precursor pollutants would exceed the thresholds to model those emissions in order to determine whether such emissions could potentially cause the air quality of any State to exceed the NAAQS. To ensure that OCS operations do not cause any such impact to the air quality of a State, the proposed rule would require large emitters of air pollutants, namely, those whose facilities exceed BOEM’s EETs—not only to project their emissions in their plan, but also to demonstrate that their actual emissions do not exceed their projected emissions (as contained in their original plan). To ensure ongoing compliance, three major new procedures have been proposed. First, under the proposed rule, if the USEPA revises any AAQSB that applies (NAAQS, or any applicable SIL, or AAI), BOEM would examine the appropriateness of its EETs, and, BOEM, at its discretion, would periodically revise its EETs for the air pollutant(s) corresponding to USEPA’s revision(s). Second, certain large emitters would be required to develop a method for measuring and reporting their emissions to demonstrate their actual emissions do not exceed the original projections upon which approval was granted. Third, starting in 2020,5 all lessees and operators with previously approved plans would be required to update their plans with then current emissions data, and BOEM would re-evaluate all of these updated plans against the current EETs and for compliance with current AAQSB, according to a schedule proposed in 550.310(c)(2). All lessees and operators that submit plans would be required to include up-to-date emissions data in their plans to ensure they comply with then current AAQSB. Although BOEM does not issue air quality permits and instead reviews air emissions in the context of its AQRP, BOEM recognizes that a one-time review of a particular facility’s compliance with AAQSB may not be adequate to ensure that the facility does not cause or 5 BOEM is proposing this date because BOEM expects that it will have completed the studies to set new EETs by that time. E:\FR\FM\05APP2.SGM 05APP2 19722 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS contribute to a violation of the NAAQS within a State. USEPA periodically updates the NAAQS and adds new averaging times and statistical forms for the various indicator pollutants. Measurement and evaluation techniques and methods are expected to improve over time. Equipment ages and becomes less efficient as it does so. The types and characteristics of support vessels, vehicles and aircraft may change. For these and various other reasons, BOEM has proposed that evaluating a plan’s effectiveness more than once may aid BOEM in ensuring ‘‘compliance with the national ambient air quality standards pursuant to the Clean Air Act (42 U.S.C. 7401 et seq.), to the extent that activities authorized under [OCSLA] significantly affect the air quality of any State’’ (43 U.S.C. 1334(a)(8)). Consistent with the requirement in every offshore lease that lessees and operators are required to comply with changes to the regulations, as they are refined, BOEM is proposing plans be reevaluated periodically for air quality purposes.6 Finally, this rule proposes to codify the existing mechanism BOEM uses in the GOM OCS Region to report ongoing emissions information (i.e., the Gulfwide Offshore Activities Data System or GOADS, as described in Notice to Lessees and Operators ([NTL], BOEM NTL No. 2014–G01) and apply it to all OCS regions under BOEM air quality jurisdiction. This information is important to ensure that OCS activities authorized by BOEM do not cause any State to exceed the NAAQS. BOEM also uses this information in its National Environmental Policy Act (NEPA) documents at several stages of the OCS leasing and plan review and approval process. In addition, BOEM shares this data with the USEPA to enhance its national emissions inventory (NEI), and with States and local air quality management agencies for the development of State Implementation Plans (SIPs). In-addition, BOEM collects emissions information related to Greenhouse Gases (GHGs) on a regular basis as part of the GOADS program and provides this information to lessees and operators to facilitate their reporting to the USEPA. three to nine nautical miles (nm) offshore (this varies by State) to the extent of U.S. claimed jurisdiction and control, which is 200 nm or more from the coastal States’ baseline.7 BOEM makes OCS resources available for expeditious and orderly development through leasing, subject to environmental safeguards, in a manner that is consistent with the maintenance of competition and other national needs (43 U.S.C. 1332(3)). In 1978, OCSLA was amended to include a requirement for DOI to promulgate regulations for ‘‘compliance with the national ambient air quality standards pursuant to the CAA (42 U.S.C. 7401 et seq.), to the extent that activities authorized under [OCSLA] significantly affect the air quality of any State’’ (43 U.S.C. 1334(a)(8)). In 1980, the USGS, a BOEM predecessor agency responsible for overseeing OCS energy and mineral activity, promulgated air quality regulations for activities authorized on the entire OCS, which are now BOEM’s air quality regulations. In 1990, Congress amended section 328 of the CAA and transferred authority to regulate air emissions on the OCS, other than in the Central and Western GOM, from DOI to the USEPA. In 2011, Congress again amended section 328 to transfer the authority for regulating air emissions from the USEPA back to DOI for those parts of the OCS adjacent to the North Slope Borough of the State of Alaska. As of the publication of this proposed rule, DOI’s jurisdiction for ensuring compliance with the NAAQS pursuant to the CAA includes OCS areas adjacent to Texas, Louisiana, Mississippi, Alabama, and the North Slope Borough of the State of Alaska. III. Background 7 The official U.S. coastal baseline is recognized as the low-water line along the coast in accordance with the articles of the United Nations Convention on the Law of the Sea, art. 76, Dec.10, 1982, 1833 U.N.T.S. 3, 428. The territorial sea extends seaward 12 nautical miles (nm) from the baseline. The Exclusive Economic Zone (EEZ) extends from the outer boundary of territorial sea seaward to 200 nm. The continental shelf begins at 12 nm, includes the EEZ and may extend further. The U.S. OCS extends from the SSB to the extent of the continental shelf. See 43 U.S.C. 1331(a); see also 43 U.S.C. 1301. A. Statutory Authority OCSLA grants DOI authority to issue leases for the development of the nation’s energy and mineral resources on the OCS. The U.S. OCS extends from 6 See § 550.310(c)(2), below, of the proposed rule text. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 B. Current Air Quality Framework—Air Quality Regulatory Program Congress has geographically divided air quality regulatory authority for authorized OCS activities between the USEPA and BOEM, based upon where those activities occur on the OCS. While the overall objectives of BOEM’s and the USEPA’s air quality regulations are similar, there are differences in each agency’s statutory authority and differences in the way each agency PO 00000 Frm 00006 Fmt 4701 Sfmt 4702 implements its statutory charge. The USEPA implements its charge through permitting (CAA Sections 165 and 173). The CAA directs the USEPA to establish requirements to control air pollution from sources on the OCS to attain and maintain federal and State ambient air quality standards and to comply with the provisions of part C of subchapter I of the CAA (CAA Section 328(a)). USEPA regulations for permitting OCS sources ‘‘ensure that there is a rational relationship to the attainment and maintenance of federal and State ambient air quality standards and the requirements of part C of title I, and that the rule is not used for the purpose of preventing exploration and development of the OCS’’ (40 CFR 55.1). The USEPA’s OCS air quality regulations incorporate requirements derived from other areas of the CAA and USEPA regulations and for sources within 25 miles of the State boundary require compliance with local rules as if the source were located onshore, the result of which is that operators must demonstrate compliance with several different types of requirements. BOEM’s jurisdiction under 43 U.S.C. 1334(a)(8) requires BOEM to promulgate regulations ‘‘for compliance with the national ambient air quality standards pursuant to the [CAA] . . . to the extent that activities under OCSLA significantly affect the air quality of any State.’’ Thus, regulations implementing this section regulate offshore emissions specifically to protect State air quality rather than protecting air quality above the OCS generally. Upon submission by a lessee or operator of a plan, BOEM will determine whether the plan is consistent with the OCSLA and BOEM’s regulations. If BOEM determines that a plan is inconsistent with OCSLA or BOEM’s regulations, BOEM will require modifications of the plan as necessary to achieve consistency. BOEM may approve, require modification of, or disapprove an EP. BOEM can disapprove an EP only if there are no possible modifications that would avoid ‘‘serious harm or damage to life (including fish and other aquatic life), to property, to any mineral (in areas leased or not leased), to the national security or defense, or to the marine, coastal, or human environment,’’ as described in 43 U.S.C. 1334(a)(2)(A)(i). With respect to a DPP or a DOCD, BOEM must approve, disapprove, or require modification of the plan after conducting a compliance review, which includes compliance with the regulations implementing section 1334(a)(8). In addition, the timing of BOEM’s decisions is also circumscribed E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules by the provisions of OCSLA. Under OCSLA, BOEM is required to approve a plan within 30 days for an EP or within 60 days for a DPP or DOCD, if BOEM finds that the plan is consistent with OCSLA and its implementing regulations, including those ensuring air quality compliance under section 5(a)(8) of OCSLA. (See 43 U.S.C. 1340(c) and 1351(h)). BOEM’s predecessor, USGS, developed the current air quality regulatory framework in 1980 to address potential onshore air quality impacts of OCS operations on adjacent States. These regulations require lessees or operators to submit information on projected air emissions in their proposed EPs, DPPs and DOCDs. BOEM considers air emissions information submitted by lessees and operators as one component of its review of the overall exploration or development plan. The regulatory process by which BOEM evaluates the submitted emissions information is referred to in this document as BOEM’s AQRP. The 1980 regulations first established a process for determining whether the potential air quality impacts from any given plan are low enough that they should be exempt from further air quality regulatory analysis. Plans that do not exceed these EETs are generally exempt from further analysis. For plans that exceed these exemption thresholds, BOEM regulations require lessees and operators to conduct modeling intended to help BOEM determine whether emissions from any facility could cause an exceedance of the AAIs or NAAQS onshore, and if so, what mitigation (i.e., emissions reduction) measures, if any, BOEM should impose on those proposed exploration and development activities to reduce the potential impacts to affected States. BOEM conducts its AQRP analysis whenever a lessee or operator proposes new exploration, development, or production operations on the OCS or submits a revised or supplemental plan, which would modify operations in a manner that could cause an increase in the release of regulated pollutants above the amounts described in a previously approved plan. The AQRP focuses on the impact of emissions from a specific exploration or development and production project and its potential onshore impacts on air quality. The AQRP does not directly regulate OCS air quality, since 43 U.S.C. 1334(a)(8) requires BOEM to focus its plan review on the potential impacts to the air quality of the States. The AQRP consists of a quantitative review of specific air quality data that informs a decision to approve, require modification of, or VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 disapprove a specific plan. Any modifications BOEM requires as a result of the AQRP review become an enforceable provision of the approved plan. As BOEM fulfills its statutory obligation, its AQRP also achieves other objectives: (1) To protect public health from adverse air quality effects; (2) to protect public welfare by preventing a deterioration in the air quality of the environment (e.g., to protect crops, forests, and wildlife); (3) to prevent the formation of new designated nonattainment areas; and, (4) to preserve and prevent degradation of the air quality in national parks and other areas of special natural, recreational, scenic, or historic value. In practical terms, this is accomplished by assessing whether OCS operations and activities will advance these objectives. The AQRP is one factor that BOEM considers in making a determination on the overall plan. The AQRP analysis is intended to account for emissions of pollutants considered harmful to public health and the environment from facility and associated support craft. The plan must include descriptions of all relevant emissions sources—offshore, stationary and nonstationary, and certain onshore ones—regardless of whether they are intended to be used on a short-term or long-term basis, and regardless of attainment status. As part of the AQRP analysis, BOEM currently evaluates the emissions of most pollutants that the USEPA has designated as NAAQS ‘‘criteria pollutants’’ (CPs) in the USEPA’s air quality regulatory scheme. The USEPA currently defines the following six pollutants as CPs: Carbon monoxide (CO); nitrogen dioxide (NO2); sulphur dioxide (SO2); ozone (O3); particulate matter (PM); and lead (Pb). BOEM evaluates air emissions using the NAAQS as a standard because OCSLA provides that BOEM must ensure compliance with the NAAQS (43 U.S.C. 1334(a)(8)). At the time the current regulations were promulgated, BOEM’s predecessor, USGS, determined that Pb was generally not released in sufficient quantities from offshore oil and gas operations to warrant a separate analysis, and so BOEM does not currently review Pb data as part of the AQRP. Also, as of 1980, the USGS had determined that there was no way to review O3 formation directly, but it instead decided to regulate O3 formation indirectly, through the tracking of O3 precursor pollutants, volatile organic compounds (VOCs) and NOX. In addition to regulating CPs, BOEM currently regulates most of the major precursor pollutants that lead to the formation of the CPs. Some CPs are also PO 00000 Frm 00007 Fmt 4701 Sfmt 4702 19723 precursors for other CPs. For example, USEPA has identified SO2 as a precursor to the formation of PM2.5, which is PM that is 2.5 micrometers in diameter or less, and both are CPs. BOEM’s current regulations address two precursor pollutants of ozone, NOX and VOCs. Ammonia (NH3) is not currently covered by BOEM’s regulations but is proposed to be regulated in this proposed rule, because it may be regulated under the Clean Air Act as a precursor pollutant to the formation of PM2.5. The USEPA has found that GHG 8 emissions endanger the public health and welfare (74 Federal Register (FR) 66496, Dec. 15, 2009). BOEM recognizes that the continued and prospective emissions of GHGs from offshore oil and gas operations will contribute to global GHG concentrations.9 The goal of this rule, however, is to implement Section 5(a)(8) of OCSLA, which requires BOEM to regulate air quality so as not to allow exceedances of the NAAQS in any State. While GHGs are not regulated under the NAAQS and are currently being addressed by the USEPA through other sections of the CAA, climate change itself impacts air quality, particularly ground-level ozone, and has consequential health impacts associated with poor air quality.10 However, because GHGs are not regulated under the NAAQS, Section 5(a)(8) of OCSLA specifically is not the appropriate statutory vehicle to address the harm that GHGs cause and BOEM is not proposing to address the issue of GHG emissions in this proposed rule. The Bureau, however, is still interested in addressing GHGs 8 GHGs are defined by the USEPA as the aggregate group of the following six greenhouse gases: Carbon dioxide (CO2), methane (CH4), nitrous oxide (N2O), hydrofluorocarbons (HFCs), perfluorocarbons (PFCs), and sulfur hexafluoride (SF6). See, e.g., 40 CFR 52.21(b)(49)(i). 9 More recently, in the preamble to its proposed new source performance standards for the oil and gas industry, the USEPA provided an update regarding the climate change impacts that result from GHG emissions (80 FR 56593, 56602, Sept. 18, 2015). Many of the numerous impacts identified by the USEPA, such as increased severity of storms, increased water pollution (including ocean acidification), rising sea levels, loss of sea ice, and habitat loss, relate to coastal areas and the natural resources of the OCS. Both the 2009 endangerment finding and the recent proposed new source performance standards underscore that these impacts will exacerbate ongoing environmental pressures in Alaska, and will particularly impact Alaska native communities. 10 See 74 FR 66496 (No. 239, December 15, 2009), ‘‘Endangerment and Cause or Contribute Findings for Greenhouse Gases Under Section 202(a) of the Clean Air Act,’’ or the United States Global Change Research Program (USGCRP) National Climate Assessment, available at https:// nca2014.globalchange.gov/report or the Intergovernmental Panel on Climate Change (IPCC) reports available at https://www.ipcc.ch/. E:\FR\FM\05APP2.SGM 05APP2 19724 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS consistent with its legal authorities. Lessees and operators currently submit to the NEI the results of BOEM’s calculation of GHG information as part of GOADS, and GHG emissions are considered as part of the NEPA review of lease sales and post-lease approvals. In the coming months, BOEM will engage stakeholders regarding potential avenues to address GHG emissions, as appropriate, either through a separate rulemaking or some other action. Separate but related to the GHG issue is the matter of black carbon (BC) dispersion and deposition in Alaska and other parts of the Arctic, which is an environmental concern. BC is a component of PM2.5, and as such would be a component of a CP that will be regulated under the proposed rule.11 The ambient concentrations of PM2.5, including BC, would be considered in any analysis of the pre-existing background pollution levels before any plan could be approved for development on the OCS. Recent scientific studies 12 have indicated that BC can be a source of negative health effects.13 BOEM is actively investigating this issue and our evaluation of the potential impacts of BC and a determination of appropriate controls is continuing to evolve. BOEM and the USEPA are coordinating their efforts on this matter. In addition to the health effects associated with the PM2.5 emissions that include BC, there are also potentially significant implications to climate change and global warming from BC. These relate primarily to three factors: (1) BC particles directly absorb sunlight and reduce the planetary albedo 14 when 11 Black carbon is not classified as a unique CP and the USEPA does not directly regulate its emissions other than as a component of PM2.5. 12 For example, ‘‘Black Carbon Exposures, Blood Pressure, and Interactions with Single Nucleotide Polymorphisms in MicroRNA Processing Genes,’’ in Environmental Health Perspectives, 118:943–948 (2010), and ‘‘Long-Term Exposure to Black Carbon and Carotid Intima-Media Thickness: The Normative Aging Study’’ in Environmental Health Perspectives, 121:1061–1067 (2013). Web addresses for these studies described are at: https:// www.jstor.org/stable/27822949?seq=1#page_scan_ tab_contents and https://dash.harvard.edu/handle/ 1/11877015. 13 Based on an assessment of the scientific evidence for health effects associated with exposures to ambient PM, in the most recent review of the NAAQS for PM, the USEPA concluded that ‘‘many constituents of PM can be linked with differing health effects and the evidence is not yet sufficient to allow differentiation of those constituents or sources that are more closely related to specific health outcomes’’ (PM Integrated Science Assessment (ISA), section 2.4.4). 14 Albedo is the fraction of solar energy (shortwave radiation) reflected from the Earth back into space. It is a measure of the reflectivity of the earth’s surface. Ice, especially with snow on top of it, has a high albedo: Most sunlight hitting the surface bounces back towards space. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 suspended in the atmosphere; (2) BC absorbs incoming solar radiation, disturbs the temperature structure of the atmosphere, and influences cloud cover; and (3) when deposited on high albedo surfaces like ice and snow, BC particles reduce the total surface albedo 15 available to reflect solar energy back into space. Small initial snow albedo reduction may have a large radiative forcing effect 16 because of a positive feedback: Reduced snow albedo increases surface temperatures and the increased surface temperature decreases the snow cover and further decreases surface albedo.17 While BOEM does not currently have sufficient data to support a specific limit on BC, the exemption thresholds research study currently underway for the Gulf of Mexico (which is described in detail in section III.D.1, under the heading of ‘‘Exemption Threshold Analysis’’) will analyze BC as part of the overall review. The study will apply the Community Multi-scale and Air Quality (CMAQ) Model and the Comprehensive Air Quality Model with Extensions (CAMX) photochemical grid models, as part of the analysis. PM emissions specified in the emissions inventory will be allocated to individual PM species 18 as part of the Sparse Matrix 15 Total surface albedo is the diffuse reflectivity or reflecting power of a surface. It is the ratio of reflected radiation from the surface to incident radiation upon it. In this case, the reduction in total surface albedo would represent the reduction in albedo that is caused by the relevant OCS operations in the vicinity of the project or development that is generating BC emissions. 16 Radiative forcing or climate forcing is defined as the difference of insolation (sunlight) absorbed by the Earth and energy radiated back to space. 17 Mollie Bloudoff-Indelicato (January 17, 2013). ‘‘A Smut Above: Unhealthy Soot in the Air Could Also Promote Global Warming: Atmospheric black carbon is not only bad for the lungs, but can also act as greenhouse particles under certain circumstances.’’ Scientific American. January 22, 2013. IPCC, Changes in Atmospheric Constituents and in Radiative Forcing, in Climate Change 2007: The Physical Science Basis. Contribution Of Working Group I To The Fourth Assessment Report Of The Intergovernmental Panel On Climate Change 129, 132 (2007), available at https://www.ipcc.ch/ ipccreports/ar4-wg1.htm. (Magnitudes and uncertainties added together, as per standard uncertainty rules). V. Ramathan and G. Carmichael, Global and regional climate changes due to black carbon, 1 NATURE GEOSCIENCE 221–22 (23 March 2008) (‘‘The BC forcing of 0.9 W m–2 (with a range of 0.4 to 1.2 W m–2) . . . is as much as 55% of the CO2 forcing and is larger than the forcing due to the other GHGs such as CH4, CFCs, N2O or tropospheric ozone.’’). 18 There are many forms of PM. The U.S. National Research Council has emphasized the importance of examining the risk of PM species (‘‘Research Priorities for Airborne Particulate Matter: IV: Continuing Research Progress.’’ Washington, DC, National Research Council, 2004). Determining the differential toxicity of PM2.5 species and identifying PO 00000 Frm 00008 Fmt 4701 Sfmt 4702 Operator Kernel Emissions (SMOKE) emissions processing and modeling system 19 using PM speciation factors obtained from USEPA’s SPECIATE database 20 for each source category (as defined by the Source Classification Code (SCC)). This evaluation will result in PM mass being broken into the mass associated with elemental carbon (EC), organic carbon, and other elements, as well as particle bound VOCs, such as polycyclic aromatic hydrocarbons. BC is essentially equivalent to the EC portion of PM. CMAQ 21 and CAMX 22 model projections of EC will be calculated and modeled for further analysis. This will be done both for the domain defined for the study (see section III.D.1), and for specific sources. Two other models commonly used by the industry and BOEM to evaluate air quality, AERMOD 23 and CALPUFF,24 are being considered for use and will apply a similar technique to apportion PM2.5 mass for a BC analysis. BOEM requests comments and data on the extent of BC emissions from OCS-related operations and potential means of reducing such emissions and their negative effects. BOEM also requests comment on other factors, information, or data that BOEM should consider in its analysis of BC, either in connection with or in addition to its air quality regulatory analysis. species with greatest toxicity is of great importance to emission-control strategies and regulations. These investigations have reported numerous components that may be responsible for particle toxicity, such as elemental and organic carbon, sulfate, nitrate, and metals including zinc, nickel, iron, potassium, and chromium. 19 See the following site for additional information on the SMOKE modeling system: https://cmascenter.org/smoke/. 20 SPECIATE is the USEPA’s repository of volatile organic gas and PM speciation profiles of air pollution sources. For additional information, see: https://www.epa.gov/ttnchie1/software/speciate/. 21 Further information on CMAQ is available at: https://www.fhwa.dot.gov/environment/air_quality/ cmaq/. 22 Further information on CAMX is available at: https://www.camx.com/. 23 AERMOD is described in detail in the publication, ‘‘AERMOD: DESCRIPTION OF MODEL FORMULATION,’’ U.S. Environmental Protection Agency, EPA–454/R–03–004, September 2004, available at: https://www.epa.gov/scram001/7thconf/ aermod/aermod_mfd.pdf. 24 CALPUFF is an advanced non-steady-state meteorological and air quality modeling system adopted by the USEPA in its Guideline on Air Quality Models as the preferred model for assessing long range transport of pollutants and their impacts on federal Class I areas and on a case-by-case basis for certain near-field applications involving complex meteorological conditions. Further information on this model is available at: https:// www.src.com/. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules C. Current Air Quality Regulatory Program Data Requirements As explained above, BOEM’s AQRP review, conducted under existing regulations at 30 CFR part 550 subparts B and C, is triggered when a lessee or operator submits or resubmits an exploration or development plan. With respect to air quality, BOEM currently requires the submitter to provide the following information: 1. Projected Emissions Under existing BOEM regulations, the lessee or operator must provide tables showing the projected air emissions of all regulated criteria and major precursor pollutants, except PM2.5, Pb, and O3,25 generated by the submitted plans. In addition, for each source for each pollutant, lessees must identify: The projected hourly emissions rate in peak pounds per hour; the total projected annual emissions in tons per year (tpy); the frequency and duration of projected emissions; and all projected emissions over the duration of the plan (i.e., for as many years as the operations will continue). asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 25 Existing BOEM air pollution prevention and control regulations (30 CFR part 550 subpart C) apply air quality standards and screening methods current as of 1980. At that time PM2.5 was not regulated and all PM was considered as total suspended particulates (TSP). Neither Pb nor O3 were included in the USEPA’s screening methods under 40 CFR 52.21(c) or 40 CFR 165(b)(2). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 2. Maximum Potential Emissions The lessee or operator must base all of its projected air emissions identified in (1) above on the maximum rated capacity of the equipment on the plan’s drilling unit or facility. 3. Processes, Equipment, Fuels, and Combustibles The lessee or operator must provide a description of processes, processing equipment, combustion equipment, fuels, and storage units, including the characteristics and the frequency, duration, and maximum burn rate of any well test fluids to be burned. 4. Distance to Shore The lessee or operator must provide the distance between any given facility and the closest shoreline of an adjacent State. 5. Emission Reduction Measures (ERM) Each lessee or operator must describe any proposed air emission reduction measures (ERM), including a description of the relevant source(s), the emission reduction control technologies or procedures, the quantity of reductions to be achieved, and any monitoring system proposed to measure emissions. 6. Reductions in Emissions From NonExempt Drilling Units The lessee or operator must provide a description of how the lessee or PO 00000 Frm 00009 Fmt 4701 Sfmt 4702 19725 operator intends to address the emissions generated, if emissions from the plan are greater than the lessee’s or operator’s respective emissionexemption amounts and if modeling indicates that some form of emissions reductions will be necessary. 7. Documentation The lessee or operator must document the basis for all of its calculations, including engine size, rating, and applicable operational information. In the GOM region, BOEM and industry have historically used worksheets contained in forms BOEM–0138 (Gulf of Mexico Air Emissions Calculations for EPs) and BOEM–0139 (Gulf of Mexico Air Emissions Calculations for DOCDs) for air quality information. D. Proposed Analytical Approach 1. Flowchart The following flow chart illustrates the analytical approach that a lessee or operator would use to evaluate its projected emissions under this proposed rule. The flow chart is intended for informational purposes only. In any circumstances where the flow chart may be interpreted to conflict with the regulatory text, the regulatory text is controlling. [See attached flowchart] BILLING CODE 4310–MR–C E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Jkt 238001 PO 00000 Frm 00010 Fmt 4701 Sfmt 4725 E:\FR\FM\05APP2.SGM 05APP2 VOC emissions so Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules 22:26 Apr 04, 2016 EP05AP16.000</GPH> 19726 VerDate Sep<11>2014 EET is notftKceeded. c 550 CFR P):_ Program Iat() BOEMAir VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00011 Fmt 4701 Sfmt 4725 E:\FR\FM\05APP2.SGM 05APP2 19727 EP05AP16.001</GPH> asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19728 VerDate Sep<11>2014 Jkt 238001 Modeling under Step 5 PO 00000 Frm 00012 Fmt 4701 Sfmt 4725 E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules 22:26 Apr 04, 2016 EP05AP16.002</GPH> c While many significant changes would be made to BOEM’s AQRP under VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 the proposed rule, the analytical framework remains fundamentally the PO 00000 Frm 00013 Fmt 4701 Sfmt 4702 19729 same. Under both the current regulations and the proposed rule, the E:\FR\FM\05APP2.SGM 05APP2 EP05AP16.003</GPH> asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules 19730 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS lessee or operator must perform the following fundamental steps: (1) Identify and describe the characteristics of all the relevant emissions sources; (2) calculate the emissions associated with these sources; (3) determine which emissions should properly be allocated to the lessee’s or operator’s plan; (4) compare the emissions totals, on a perpollutant basis, to a series of exemption formulas; (5) apply ERMs to sources of VOC emissions that exceed the VOC exemption threshold; (6) conduct modeling of the potential impacts for any criteria pollutant that exceeds an exemption threshold and compare against various AAQSB; and (7) propose emission reduction measure(s) as necessary to ensure compliance with those standards and benchmarks. The ‘‘Summary of Key Changes’’ section of this preamble outlines the major changes included in this proposed rule. While the basic steps of the AQRP process would remain similar, the proposed rule would alter how the data are gathered, the standards and benchmarks against which the data are evaluated, and the process by which the air quality information is reviewed. BOEM’s current air quality evaluation methodology is based in large part on the USEPA’s New Source Review (NSR) pre-construction permitting program.26 Under one part of that program, USEPA uses pollutant-specific emission rates (called Significant Emissions Rates) to determine whether a permit applicant is required to conduct an ambient air quality analysis for each pollutant.27 If so, USEPA then uses concentration levels known as SILs to help determine whether an individual source will cause or contribute to an exceedance of the NAAQS and the level of analysis necessary to make that determination. BOEM uses emission exemption thresholds to determine whether the 26 The NSR pre-construction permitting program is mainly composed of two parts: The Prevention of Significant Deterioration (PSD) program in attainment areas and the New Source Review Program for non-attainment areas. The PSD program applies to any ‘‘major emitting facility,’’ including any OCS source, that commences construction or undertakes a major ‘‘modification’’ in an attainment area (CAA sections 165(a) and 169(2)(C)). A ‘‘major emitting facility’’ or ‘‘major source’’ is a stationary source that emits or has the potential to emit (PTE) any air pollutant in the amount of at least 100 or 250 tpy, depending on the source category and irrespective of the facility’s location. A major ‘‘modification’’ is any physical or operational change to a stationary source that would result in both a significant emissions increase and a significant net emissions increase of one or more regulated NSR pollutants. A new major source or major modification must apply BACT, which is determined on a case-by-case basis taking into account, among other factors, the cost effectiveness of the control and energy and environmental impacts (40 CFR 52.21(b)(12) and (j)). 27 40 CFR 52.21(b)(23); 40 CFR 52.21(m)(1)(i). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 lessee’s plan emissions would potentially impact the air quality of the State. When the thresholds are not exceeded, those emissions are presumed to not cause or contribute to an exceedance of the NAAQS. The USEPA uses applicability thresholds to determine if a source is subject to the requirements of the respective parts of the NSR permitting program and then applies screening criteria like the SILs 28 to determine whether emissions per pollutant require further regulatory review. Given BOEM’s distinct mandate to focus on State impacts from OCS activities, BOEM currently uses a formula that accounts for the distance of the facility from the shoreline. Specifically, the determination as to whether a facility could significantly affect onshore air quality under BOEM’s AQRP is based on a formula that considers both the amount of air pollutant emitted and the distance of the proposed facility from the shoreline.29 Because BOEM’s determination of what constitutes potentially significant emissions varies depending on a proposed facility’s distance from shore, BOEM uses distance as a variable in its formula to determine the relevant EET. If a proposed plan would cause emissions of criteria or precursor air pollutants in excess of the EET, the proposed plan is required to include a detailed air quality analysis. If a proposed plan would not cause emissions of criteria or precursor air pollutants in excess of the EET, the plan is not required to include a detailed air quality analysis. BOEM refers to plans that are not required to include a detailed air quality analysis as ‘‘exempt.’’ 2. Exemption Threshold Analysis The first step in the approach of both the current regulations and the proposed rule is the exemption threshold analysis discussed above. BOEM determines, based on the 28 The SILs are benchmarks used by the USEPA to determine whether some area may potentially be significantly affected by the emissions generated from a proposed new stationary source of emissions. The SILs are used as a screening tool to determine what additional steps, if any, may be required before a stationary source can be approved. 29 This differs from the way in which the USEPA determines which facilities are subject to the NSR preconstruction permitting program. As explained in the previous footnote, the USEPA makes this determination based on whether the emissions of a new source or modification to an existing source are higher than a certain amount of tons of air pollution per year or whether the modification would result in both a significant emissions increase and a significant net emissions increase of one or more regulated NSR pollutants irrespective of the facility’s or facilities’ location. PO 00000 Frm 00014 Fmt 4701 Sfmt 4702 information provided by the lessee or operator, whether or not any given plan (EP, DPP or DOCD) will generate emissions above a defined exemption threshold. If so, further analysis is required. If not, the impact to the air quality of the State is presumed to be de minimis and no further action is required. BOEM currently has only one set of exemption thresholds, which are, under the existing regulations, applied identically in the Central and Western GOM OCS Regions and offshore of the North Slope Borough of the State of Alaska. BOEM is now in the process of conducting scientific studies to reevaluate the exemption thresholds formulas, for both the GOM and Alaska OCS Regions to tailor those thresholds to the relevant environmental characteristics of each region and to take into consideration USEPA standards applied to various time periods, whether annual or shorter intervals. These BOEM studies will evaluate and, if necessary, provide the basis for updating the current exemption threshold equations and consider whether recent advances in the field of computer simulation modeling and the availability of comprehensive meteorological datasets unique to each region may be applied to improve the exemption threshold equations by applying the updated underlying data. The studies will use computersimulated air quality dispersion and photochemical modeling to provide the information necessary to evaluate the current threshold equations (i.e., for the EETs) and, if necessary, establish a basis for developing a new method. All modeling conducted for the studies will be consistent with the USEPA’s Guideline on Air Quality Models (40 CFR part 51 appendix W). The GOM and Alaska OCS studies are designed to fulfill the following objectives: • Prepare onshore and offshore emissions inventories for use in computer simulation air quality dispersion and photochemical modeling, based on the multi-sale 2017–2022 scenario emissions for both OCS Regions; • Evaluate current meteorological data and develop new data, as necessary, for input into air quality models; • Conduct air quality dispersion and photochemical modeling to discern the collective effect of onshore and offshore emissions on the onshore area of adjacent States; • Investigate the current exemption threshold formulas for evidence the rates are protective of the annual and short-term (24hours or less) AAQSB using dispersion and photochemical air quality modeling and, if necessary, develop a new method; E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules • Conduct visibility analyses for the GOM Region Class I areas: Breton Wilderness; Saint Marks Wilderness; Chassahowitzka Wilderness; and Bradwell Bay; and, • Perform a 40 CFR part 51 appendix W section 3.2.2 ‘‘Equivalency Demonstration’’ for modeling purposes in the GOM region. Such an ‘‘Equivalency Demonstration’’ would involve determining the most appropriate model for the exemption thresholds, taking into account the USEPA list of preferred models and the relevant criteria for evaluating alternatives. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS As discussed above, BOEM is considering establishing two or more sets of EETs (i.e., per pollutant, averaging time, and location), at least one for the GOM OCS Region and at least one for the area offshore of the North Slope Borough of the State of Alaska. For this reason, BOEM would like comments on the appropriateness of potentially distinct emissions thresholds or threshold formulas for these two areas, and/or how these thresholds should be structured. The USEPA recently established new one-hour NAAQS for NO2, and SO2, as well as changes to the 8-hour O3 and annual PM2.5 NAAQS, and also given that the USEPA has recommended an interim SIL for one-hour NO2 at 8mg/ m3 30 and an interim SIL for one-hour SO2 at 3 parts per billion,31 but has not proposed to add these SILs (or any SILs for PM2.5 or ozone) to 40 CFR 51.165(b)(2), comments are solicited on how these new ambient standards and SILs that have the status of only being USEPA recommendations should be implemented in the context of the new studies, for the purpose of updating the new EETs that result. Until such time as new EETs are established, the existing exemption thresholds will continue to apply identically in both regions. 3. Modeling Analysis In the event the exemption threshold analysis indicates that one or more criteria or major precursor pollutants would exceed an applicable threshold, the plan submitter must proceed to the second step in the BOEM AQRP, which is the modeling analysis. The purpose of the modeling analysis is to help BOEM determine, based on the information provided by the lessee or operator, whether or not the proposed operations that generate emissions above an exemption threshold would cause or contribute to a violation of the NAAQS.32 BOEM’s AQRP currently 30 Available at: https://www3.epa.gov/nsr/ documents/20100629no2guidance.pdf. 31 Available at https://www.epa.gov/sites/ production/files/2015-07/documents/appwso2.pdf. 32 Under this proposed rule, the modeling analysis would also be used in certain cases to VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 models the onshore concentrations created by the relevant criteria or precursor pollutants emitted offshore. Under existing regulations, plans that would result in operations or uses that generate ambient concentrations above these Significance Levels as modeled onshore are subject to further review and analysis. BOEM’s Significance Levels are listed in its regulations at 30 CFR 550.303(e). These Significance Levels in BOEM’s existing regulations are based on USEPA’s SILs (as they existed approximately 35 years ago), which are ambient concentration levels used by the USEPA to determine whether the ambient air concentration of any given air pollutant could cause or contribute to a violation of the NAAQS at a given location. Under USEPA’s historical practice in the PSD program, if the ambient air impacts of each criteria air pollutant are below the applicable SILs for all relevant averaging times, then the incremental emissions are considered to have an impact that is de minimis and, therefore, not significant. BOEM’s regulations utilize the USEPA’s SILs to determine whether emissions of any given pollutant that originates offshore could have a potentially significant effect onshore. The USEPA SILs are expressed in terms of pollutant concentrations averaged over a specific period of time (i.e., averaging time), for example on an annual basis. There are also SILs designed to evaluate peak emissions of air pollutants over shorter time intervals, which include the 1hour, 3-hour, 8-hour, and 24-hour averaging times. By incorporating the relevant USEPA values listed in a table in an USEPA regulation, BOEM would automatically apply these timing intervals or averaging times, as well for those pollutants and averaging times that are reflected in USEPA regulations. Under BOEM’s existing regulations, in order to evaluate the potential onshore effects of offshore emissions, the models project the ambient concentration of any given air pollutant at various measurement points onshore, which are referred to as receptor locations. If any projected concentration of a given air pollutant does not exceed BOEM’s applicable Significance Level(s) at all receptor locations onshore for all relevant averaging times, then the incremental emissions are presumed de minimis, and no further analysis is required of emissions of that pollutant under the BOEM AQRP. In other cases, determine whether an exceedance of the AAIs has occurred; this is not listed separately, since the purpose of the AAI analysis is to protect an attainment area from potentially exceeding the NAAQS. PO 00000 Frm 00015 Fmt 4701 Sfmt 4702 19731 additional modeling and/or the application of relevant emissions reductions measures will generally be required. At the time the current BOEM regulations were promulgated, there were no USEPA-approved modeling approaches to quantify the impacts of single sources of volatile organic compound (VOC) emissions on ambient O3 levels. For this reason, the current rule does not require modeling of VOCs and there is nothing analogous to a SIL to indicate ambient impact of VOCs. Instead of evaluating VOC emissions against a SIL, VOCs are evaluated only against an exemption threshold. CPs and the reductions in their emissions that may be required under the current regulations are determined based on several different levels that can vary with the location of the facility, the attainment status of the areas it affects, and whether the facility is long- or short-term. In contrast, in those situations where the emissions of VOCs exceed the relevant emission exemption threshold, BOEM’s regulations instead require a reduction in the emissions of VOCs 33 Based on the analysis done at the time, BOEM concluded that this reduction should have been sufficient to address the potential impact of VOCs on the formation of O3.34 4. Controls for Short-Term Facilities If it is determined through modeling that the planned operations will generate an onshore concentration of one or more air pollutants in excess of the SILs, various further analyses must be done in order to determine what controls must be applied. Under the current AQRP, if a facility is projected to cause ambient concentrations of air pollution above acceptable levels (i.e., the SILs), the lessee or operator of that facility must propose the application of BACT 35 in connection with post-control modeling, to demonstrate the AAQSB will likely be met. The requirements applicable to making this determination 33 When VOC emissions exceed the EET for a short-term facility or a long-term facility affecting only an attainment area, the lessee or operator must apply ERM to reduce VOC emissions to the greatest extent possible. For a long-term facility affecting a non-attainment area, the lessee or operator must apply ERM to reduce VOC emissions so that the EET is not exceeded. 34 Results of the ongoing studies in the GOM and Alaska will provide an updated method for evaluating VOC contributions to ambient ozone concentrations in the future. 35 In this proposed rule, references to BACT are intended to refer to BOEM’s current or proposed requirements, unless the USEPA’s definition is specifically referenced. Under the USEPA regulations, most types of ERM could qualify as BACT, whereas BOEM’s definition is substantially limited to physical or mechanical controls. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19732 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules sufficient for BOEM to conclude, without further analysis, that the facility does not cause a significant effect on the air quality of a State. As explained in the next Section, this presumption would not apply in the case of a longterm facility. Although BOEM would set the air emissions limits in connection with its approval of the plan, BSEE would be responsible for ensuring that any required ERM, including BACT, are actually applied in compliance with the plan requirements. vary depending on the amount of time that the facility described in the proposed plan is anticipated to be present at any given location. The current regulations make a distinction between temporary and permanent facilities. Under the proposed rule, the phrase ‘‘short-term facility’’ is used instead of the phrase ‘‘temporary facility.’’ In both cases, these terms refer to a facility that is located in one place for less than three years. Under the proposed rule, if the projected concentration increase due to emissions from the proposed short-term facility exceeds the SILs but such exceedance only affects attainment areas, the lessee or operator would be required to determine the maximum amount of emissions reductions that it can achieve with operational controls and/or equipment replacements that are technically and economically feasible. This would represent a level of emissions reductions that achieves the maximum efficiency of their operations with respect to emissions reduction. At that point, the lessee or operator could decide whether to apply those operational controls and/or equipment replacements, or to instead obtain emissions credits. If it is determined that there are no operational controls and/or equipment replacements that are technically and economically feasible, and the emissions from the proposed facility would affect only attainment areas, then no ERM would be required. In BOEM’s proposed rule, a maintenance area is treated as an attainment area; thus, the same requirements would apply. If the projected emissions for the proposed short-term facility exceed the SILs and such exceedance would affect a designated non-attainment area, the lessee or operator would not only be required to conduct an ERM analysis, but might also be required by the Regional Supervisor to apply additional types of ERM (beyond that which was proposed in the original plan). Under the proposed rule, described in more detail in the section-by-section analysis for section 550.306, a process has been outlined to facilitate the determination of the most appropriate ERM, of which BACT is one option. If the lessee or operator proposes to use BACT, the lessee or operator would be required to provide a description of the associated energy, environmental and economic impacts,36 and other costs. In the case of a short-term facility, the application of ERM would generally be 5. Controls for Long-Term Facilities If emissions from a long-term facility generate onshore concentrations of air pollutants in excess of the SILs, under the current regulations, the lessee or operator must apply BACT. If only an attainment area is affected, the proposed BACT must result in the plan or facility meeting the Maximum Allowable Concentration Increases (MACIs), which are set out in a table in BOEM’s regulations. The MACIs are based on the USEPA’s AAIs, and are designed to prevent the air quality in clean areas from deteriorating to an unacceptable level as set by the NAAQS. The NAAQS represent a maximum allowable concentration ‘‘ceiling’’ for each air pollutant and averaging time that does not vary geographically. A MACI, on the other hand, represents the maximum increase in concentration that is allowed to occur above a baseline concentration for any given pollutant. Baseline concentrations vary geographically. When the MACI 37 is added to the baseline concentration, the result is a new ‘‘ceiling’’ specific to that area. A significant deterioration in the air quality is said to occur when the concentration of a pollutant would exceed the applicable MACI added to the baseline concentration in that area. BOEM and its predecessors have taken the position that the exceedance of a MACI constitutes a significant deterioration in air quality that ‘‘significantly affect[s] the air quality of any State.’’ Moreover, the MACIs are designed to ensure that attainment areas do not fall out of attainment, and so they are appropriate increments to ‘‘ensure compliance with the [NAAQS].’’ Thus an activity that has the potential to cause an exceedance of the MACIs should not be approved under BOEM’s current regulations. These MACIs, and the AAIs on which they were based, vary depending on whether any given location is defined as a Class I, a Class II or Class III location 36 The description of the associated energy, environmental and economic impacts is not required in the case of non-BACT ERM. 37 Under BOEM’s current regulations, the term MACI is used. This proposed rule would eliminate that term and use the term AAI exclusively. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00016 Fmt 4701 Sfmt 4702 (described below in the discussion of the definitions of those terms) and the relevant timeframes of exposure (i.e., averaging times). Under the proposed rule, with respect to impacts in an attainment area, if emissions from a long-term facility were to generate concentrations of air pollutants landward of the SSB in excess of the SILs, the lessee or operator would be required to undertake an ERM analysis, excluding BACT, to determine the most effective and technically and economically feasible approach for reducing the projected emissions from its facility. If the projected concentration increase due to emissions from the proposed facility exceed the SILs but do not exceed the AAIs, the proposed plan could be approved without the lessee or operator having to bring the concentration increase due to the emissions from its operations below the SILs. If the projected emissions exceed the AAIs after the application of ERM, the lessee or operator would be required to use additional ERM until it could demonstrate its emissions no longer resulted in such an exceedance. Under the proposed rule, with respect to impacts in a non-attainment area, if emissions from a long-term facility were to generate concentrations of air pollutants landward of the SSB in excess of the SILs, the lessee or operator would be required to undertake an ERM analysis, including BACT, to determine the most environmentally effective of the technically and economically feasible approaches for reducing the projected emissions from its facility. If the projected concentration increase— due to emissions from the proposed facility—continue to exceed the SILs after the application of ERM, the proposed plan could not be approved without the lessee or operator having to bring the concentration increase due to emissions from its operations below the SILs. Regardless of whether the projected emissions would affect a designated non-attainment or attainment area, the lessee or operator would be free to propose emissions credits in lieu of any other ERM to accomplish this objective. The proposed rule retains a requirement in the current regulations (in 30 CFR 550.303(g)(2)(i)(B)) that no plan can be approved if that plan would result in the generation of emissions sufficient to cause an area of a State to switch from attainment to a nonattainment status. For that reason, any long-term facility that demonstrates projected emissions in excess of the SILs would be required to demonstrate that those emissions do not cause the E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules exceedance of any NAAQS in an attainment area. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 6. Protection of Exceptional Natural Resources As part of the 1977 amendments to the CAA (Pub. L. 95–95; 91 Stat. 685), Congress mandated that the country be divided into various areas based on their sensitivity to potential problems associated with poor air quality. These amendments establish Class I, II, and III areas. The restriction on emissions are most strict in Class I areas and are progressively more lenient in Class II and III areas. In addition to the three classifications mentioned in the statute, the Federal Land Managers (FLMs) 38 have established a fourth classification which they title ‘‘sensitive Class II areas.’’ Sensitive Class II areas represent an intermediate classification intended to designate special areas, such as national monuments and national refuges that, while not subject to the same level of controls as Class I areas, require special protections above those normally afforded to typical Class II areas. Thus, parts of the country are designated as Class I or sensitive Class II areas to indicate that they have been identified for special protections. National parks, national wilderness areas, national monuments, national seashores, and other areas of special national or regional natural, recreational, scenic, or historic value are generally designated as Class I 39 or as sensitive Class II areas. FLMs, including the U.S. Department of Agriculture’s Forest Service, and DOI’s Bureau of Land Management (BLM), National Park Service (NPS) and U.S. Fish and Wildlife Service (FWS) manage these areas. Together, these FLMs have the affirmative responsibility to protect the unique attributes and air quality of Class I and sensitive Class II areas. BOEM has not proposed and does not intend to 38 The Federal Land Managers’ Air Quality Related Values Work Group (FLAG) was formed to develop a more consistent approach for the Federal Land Managers (FLMs) to evaluate air pollution effects on their resources. Of particular importance is the New Source Review (NSR) program, especially in the review of Prevention of Significant Deterioration (PSD) of air quality permit applications. For a facility located in or near a Class I area, the PSD permitting program uses AQRVs when evaluating the potential impact of a proposed source or modification on resources which are sensitive to air quality. 39 Several tribes have also requested USEPA to redesignate their lands from Class II to Class I to provide additional air quality protection. These are the Northern Cheyenne Reservation, the Flathead Indian Reservation, the Fort Peck Indian Reservation, the Spokane Indian Reservation and the Forest County Potawatomi Community Reservation. See 40 CFR 52.1382(c), 52.2497(c) and 52.2581(f). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 evaluate air quality impacts in nonsensitive Class II or Class III areas other than by applying the typical AQRP requirements. Under the CAA, FLMs are charged with reviewing available information about proposed facilities in order to determine their potential air quality impacts on Class I areas. FLMs have established Air Quality Related Values (AQRV), which represent resources which are sensitive to air quality and include a wide array of vegetation, soils, water, fish and wildlife, and visibility. The goal of the FLMs is to ensure that pollution levels stay below the critical loads (i.e., below which they have determined there would be no adverse impact to a Class I area). These AQRVs include values designed to protect visibility, odor, flora, fauna, and geological, archeological, historical, and cultural resources, as well as soil and water resources. The AQRVs for various Class I areas differ depending on the purpose and characteristics of a particular area and the assessment by an area’s FLM. The FLMs determine the requirements for compliance with each AQRV.40 FLMs evaluate plans submitted to BOEM to determine whether there would be any potential adverse impact to a Class I or sensitive Class II area and to recommend controls, as appropriate, if there are potentially adverse impacts. In order to complement this process, BOEM’s AQRP requires any proposed long-term facility whose emissions cause an exceedance of the SILs to meet the standards for the MACIs that correspond to the Class designation of the areas onshore of the proposed operations. 7. Primary and Secondary National Ambient Air Quality Standards (NAAQS) Evaluation Once BOEM determines the MACIs or the SILs would not be exceeded, BOEM must make a further determination that the NAAQS would also not be exceeded in any attainment area. There are two types of NAAQS, primary and secondary. Primary NAAQS are intended to protect public health, including the health of sensitive subpopulations with a requisite margin of safety, whereas secondary standards are intended to protect public welfare (e.g., effects on crop yields) from any known or anticipated adverse effects associated with the presence of the specified pollutants in ambient air. These standards are composed of four elements: Indicator; averaging time; 40 See https://www.nature.nps.gov/air/Pubs/pdf/ flag/FLAG_2010.pdf. PO 00000 Frm 00017 Fmt 4701 Sfmt 4702 19733 statistical form; and level. Under both BOEM’s current regulations and its proposed rule, for any pollutant for which there is more than one standard, plans must comply with whichever NAAQS standard is strictest in terms of the ERMs needed for the facility. Generally, according to both BOEM and USEPA regulations, no project can be approved if it would result in design concentrations for any given air pollutant in excess of the level for either the primary or secondary NAAQS for that pollutant in an attainment area. The NAAQS, codified at 40 CFR part 50, identify the maximum allowable concentrations, or ‘‘ceilings,’’ and forms, for each of the various CPs at any given location. Under its current regulations, BOEM will not approve a plan that it determines would cause the ambient air quality either at the shoreline or farther onshore to deteriorate significantly beyond the air quality specified by the applicable NAAQS for any given air pollutant, regardless of whether the change would comply with the other relevant SIL(s) or AAI(s) for that same pollutant.41 Because the NAAQS represent the amount of an air pollutant that is allowable at any given location, evaluating the emissions of the pollutant to determine the potential for an exceedance requires information on existing concentrations of the pollutant at the location, i.e., the background concentration. The sum of the background concentration of the pollutant plus the incremental concentration of that same pollutant caused by the projected emissions for the relevant averaging time and statistical form is referred to as the design concentration of that pollutant. BOEM compares the design concentration with the NAAQS to determine if there is likely to be an exceedance. 8. Intersection With the National Environmental Policy Act Under current BOEM regulations, while the AQRP is focused on the extent 41 There could be an exception in a case where offsets are used in lieu of another ERM. In the proposed rule, the emissions credits must affect the same Air Quality Control Region (AQCR) as the facility’s projected emissions. Because the boundaries of the AQCR may not be the same as the boundaries of the non-attainment areas (because non-attainment areas are typically much smaller), and because the proposed rule would commit BOEM to always allowing offsets provided they are in the same AQCR, the effects of the facility’s pollution and the offsets may occur in different areas. Thus, it is possible that the non-attainment area may remain unaffected even after the relevant ERM have been applied. Since the offset is the same magnitude as the required reduction, the statement would be accurate on an aggregate basis, regardless of the attainment/non-attainment areas to which the offset would apply. E:\FR\FM\05APP2.SGM 05APP2 19734 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules E. Conclusion BOEM’s AQRP is intended to protect the air quality of the States and to achieve the following objectives with regard to OCS exploration and development: (1) To protect public health from adverse effects; (2) to protect public welfare, including the economies of the States, by preventing a deterioration in the air quality of the environment (e.g., to protect crops, forests, and wildlife); (3) to prevent the formation of new designated nonattainment areas; and (4) to preserve and enhance the air quality in national parks and other areas of special natural, recreational, scenic, or historic value. BOEM continues to maintain these same goals and objectives as it proposes to amend the regulations to more effectively meet these goals and objectives. In most cases, these objectives are similar to those of corresponding analysis and permit review processes of the States, working in conjunction with the USEPA. In addition to BOEM’s AQRP, the Bureau of Safety and Environmental Enforcement (BSEE) has an enforcement program designed to ensure lessees and operators comply with BOEM’s air quality regulations and that such lessees and operators do not emit air pollutants that exceed the terms of their approved plans or RUE or pipeline ROW applications. BOEM provides plan information to BSEE on a regular basis, and BSEE uses this information to evaluate applications for permits to drill. BSEE also monitors lessee or operator operations on an ongoing basis, as one component of its inspections process. 9. Additional Environmental Review asabaliauskas on DSK3SPTVN1PROD with PROPOSALS to which projected air emissions generated offshore could significantly impact the air quality onshore, BOEM also considers air quality impacts related to lease and plan approval as part of its analyses conducted pursuant to NEPA. BOEM considers potential impacts from air emissions individually and collectively, including potential air quality impacts offshore and onshore that would be caused by proposed oil and gas exploration and development activities. Because of BOEM’s staged decision-making with respect to activities conducted under an OCS lease, NEPA reviews involve multiple analyses and occur at several time points in the OCS lease and development process. In order to comply with the applicable requirements of NEPA, BOEM evaluates the likely cumulative impacts of OCS development during its Five-Year Oil and Gas Leasing Program and the associated Five-Year Programmatic Environmental Impact Statement. BOEM conducts an additional analysis of such prospective impacts at the time it prepares a multisale Environmental Impact Statement (EIS) or a NEPA analysis on an individual lease sale. BOEM conducts an even more detailed air quality analysis at the time the lessee or operator submits the EP, or RUE or ROW application, lease-term pipeline application, and again when the lessee or operator submits a DPP or DOCD. At these two later stages, BOEM conducts the AQRP in order to ensure the lessee’s or operator’s implementation proposals comply with the applicable requirements of OCSLA and the corresponding BOEM regulations. A. Air Pollution Emissions Standards The current rule has AAQSB relevant to CO, SO2, NOX, total suspended particulates (TSPs) and VOCs. The proposed rule would broaden the scope of BOEM’s AQRP to cover all the NAAQS criteria pollutants and the major precursor pollutants, as required by OCSLA. Under the proposed rule, carbon monoxide and VOCs would be subject to substantially the same requirements as under the current regulations. The review of SO2 would be expanded to also include an evaluation of other sulphur oxides (SOX). Total suspended particulates would be replaced as an indicator pollutant with a new indicator pollutant titled PM10. New regulatory requirements would be added for O3, Pb, PM2.5, and NH3, none of which have specific emissions limits in the current regulations. In addition, the requirements for hydrogen sulfide BOEM conducts analyses of the potential impact of OCS development on the conservation of the natural resources of the OCS and overlying waters (including the fish, marine mammals, plants, corals, etc.) to ensure the prevention of waste; to evaluate those circumstances that could result in environmental and other hazards; and to conserve and protect the associated mineral, economic, and environmental resources in and over the OCS, in accordance with OCSLA at 43 U.S.C. 1334(a), 1340(c), and 1351. Current BOEM regulations also specify each Regional Supervisor should evaluate every plan and make a determination that the proposed activities will not cause serious harm or damage to the marine, coastal, or human environment (e.g., 30 CFR 550.202). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 IV. Summary of Key Changes PO 00000 Frm 00018 Fmt 4701 Sfmt 4702 (H2S), a minor precursor to SO2, would be refined. The proposed rule defines BOEM’s list of criteria and precursor pollutants by reference to the relevant tables in the USEPA’s regulations, thereby ensuring that any changes or additions promulgated by the USEPA would be automatically accounted for in the BOEM regulations. In addition to accounting for all of the criteria and major precursor pollutants, as required by OCSLA, the proposed rule would result in enhanced collection, evaluation, and consideration of data on such pollutants over a greater variety of time intervals (i.e., averaging times), because BOEM would evaluate air pollutant emissions in terms of the effects, not only on annual pollution levels, but also on pollution levels for the other averaging times the USEPA uses in evaluating SILs, AAIs (MACIs) and NAAQS for CPs, including 1-hour, 3-hour, 8-hour, and 24-hour averaging times. The differing averaging times were established in recognition that higher short-term concentrations of a pollutant can have adverse effects even when the long-term average concentration of the same pollutant falls within relevant annual standards. The proposed rule would better align and coordinate the information gathering and data analysis requirements in BOEM’s regulations with similar requirements used by the USEPA and reflected in USEPA requirements and tables. Specifically, under the proposed rule, BOEM would require the use of the USEPA’s tables for SILs, AAIs and NAAQS in any circumstance where modeling is required. Thus, any changes to any applicable USEPA AAQSB would automatically be cross-referenced by BOEM regulations and would not require that BOEM amend or update its regulations. Under the proposed regulations, certain provisions within BOEM’s rules would be updated automatically whenever the USEPA makes corresponding changes in: • The SILs, also known as significant impact levels or significance levels, with the associated averaging times, as defined in 40 CFR 51.165(b)(2); • The AAIs (i.e., concentration levels of ambient pollutants and associated statistical form), as defined in 40 CFR 52.21(c); • The primary or secondary NAAQS, as defined in 40 CFR part 50; • The identification of criteria and major precursor air pollutants, as defined in 40 CFR 51.15(a); • The list of approved air quality models, as defined in 40 CFR part 51, appendix W; • USEPA air quality modeling requirements and methodologies, as defined in 40 CFR part 51, appendix W; E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules • Emissions factors, based on models defined by the USEPA or the FAA, to determine emissions levels for tier- and nontier-compliant marine and non-road engines and aircraft; • Reporting timeframes associated with the NEI; and • Significant emissions rates (SERs) for criteria and major precursor pollutants, as defined in 40 CFR 51.21(b)(23)(i). Under the proposed rule, certain provisions in BOEM’s rule would also be updated automatically whenever the USEPA changes 40 CFR 1043.100 to reflect emissions standards and other requirements applicable to marine engines under Annex VI to the International Convention for the Prevention of Pollution from Ships (as the protocol is defined in 33 U.S.C. 1901), as implemented in the U.S. through the Act to Prevent Pollution from Ships (33 U.S.C. 1901–1915). This protocol is commonly referred to as ‘‘MARPOL.’’ The MARPOL standards are part of the federal coordinated strategy to address emissions from vessels adopted by the USEPA which consists of (1) the CAA engine standards and fuel limits for U.S. vessels contained in 40 CFR 80 and 40 CFR 1042; (2) the North American and U.S. Caribbean Sea Emission Control Areas designed by amendment to the MARPOL protocol; and (3) the MARPOL engine emission and fuel sulphur limits that apply to all vessels regardless of flag (see 75 FR 22896, April 30, 2010). BOEM proposes that foreign vessels be allowed to use the MARPOL standards as emission factors for the purposes of the program, if there are no preferred, more accurate alternatives, with certain adjustments.42 In addition, as the following are modified by the USEPA, BOEM’s standards for review of plans and requirements would change correspondingly: asabaliauskas on DSK3SPTVN1PROD with PROPOSALS • The attainment or designated nonattainment status of State lands potentially impacted by emissions from OCS activities, as defined in 40 CFR part 81, subpart C; and • The Class designation of federal, State or tribal lands or waters on or potentially impacted by emissions from OCS activities, as defined in 40 CFR part 81, subpart D. B. Attributed Emissions Historically, BOEM has considered two primary sources of emissions in connection with its regulation of OCS air emissions—stationary sources, and 42 Such adjustment would be done in order to take appropriate account the deterioration in performance, based on the age of the equipment and the potential variation of the actual emissions from the standard to account for the maximum potential emissions that the emissions source may emit (as described in section 550.205(b)(2)(vii) of the proposed rule text). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 non-stationary sources, such as support vessels, over-the-ice vehicles and aircraft. The proposed rule would change the manner in which lessees and operators must consider and model emissions from support vessels and other non-stationary sources. The changes would mean that plans will more accurately reflect how emissions may affect the air quality of States, given improvements in modeling capabilities. 1. Emissions From Stationary Sources BOEM proposes relatively few changes to what constitutes the kinds of stationary sources of air emissions subject to review and/or regulation. In accordance with OCSLA, all offshore facilities constructed or operating on the OCS must be covered by an approved plan that BOEM has evaluated for compliance with relevant emissions standards. While the proposed rule would retain this basic principle, the proposed rule would expand the definition of facility to address the greater variety of facilities now being constructed. Accordingly, the proposed rule would replace any existing reference to a ‘‘drilling unit’’ with a reference to the broader term ‘‘facility’’ and would clarify that air quality and air emissions information and analysis must be provided with respect to any facility that is proposed to be located on the OCS. Further details concerning the definition of the term facility are provided in the section-by-section analysis of the new or updated definitions listed in section 550.302. The proposed rule would make clear that emissions from decommissioning activities would be included in a facility’s projected emissions. This proposed rule does not specify air quality review requirements associated with the decommissioning or removal of structures on the OCS. BOEM is soliciting information on the most appropriate method for establishing and reporting air quality requirements associated with decommissioning and structure removal activities in the context of the AQRP. This includes a request for information and comment on when and how BOEM should receive air quality emission data and information associated with decommissioning and structure removal and how an assessment of feasible ERM should be applied. One approach on which BOEM solicits comment would be whether it should provide for only the collection of emissions data associated with decommissioning activities for some period of time, followed by a second phase in which BOEM could utilize the data that was previously collected to craft an PO 00000 Frm 00019 Fmt 4701 Sfmt 4702 19735 approach tailored to this unique type of activity. 2. Emissions From Mobile Support Craft (MSC) In the proposed rule, BOEM would continue to require the collection and evaluation of emissions data related to offshore supply vessels (OSVs) and other support vessels and vehicles (collectively, mobile support craft (MSCs)) for two primary reasons. First, the data remain necessary to accurately model the impact of any given exploration or development project to determine whether the air emissions are likely to exceed the emissions thresholds, and, therefore, to determine whether the air emissions are potentially significant. Second, this proposed rule would allow BOEM to use the data to determine whether emissions associated with a project covered by a plan are at a level such that the planned operations could cause or contribute to a violation of the NAAQS in a State. BOEM’s statutory responsibility to regulate ‘‘for compliance with the [NAAQS], to the extent that activities authorized under this subchapter significantly affect the air quality of any State,’’ authorizes BOEM to take into account sources of emissions directly related to OCS operations that have the potential to significantly affect a State’s air quality.43 A portion of the emissions associated with exploration and development of OCS oil and gas come from the MSCs providing support to OCS operations. While MSC operations do not require direct BOEM authorization, their activities and the associated emissions are undertaken pursuant to contracts and orders from lessees and operators engaging in oil and gas exploration and development, which require BOEM’s approval of a plan. Without an accounting of these emissions in the plan, BOEM would not know whether emissions that will stem 43 The conference report accompanying the enactment of section 5(a)(8) of OCSLA explained: The standards of applicability the conferees intended the Secretary to incorporate in such regulations is that when a determination is made that offshore operations may have or are having a significant effect on the air quality of an adjacent onshore area, and may prevent or are preventing the attainment or maintenance of the AAQSs of such area, regulations are to be promulgated to assure that offshore operations conducted pursuant to this act do not prevent the attainment or maintenance of those standards. The terms ‘‘may have’’ and ‘‘may prevent’’ refer to the Secretarial judgment regarding future consideration of exploration plans, or development and production plans, in which the potential for ‘‘significant effect’’ is analyzed prior to approval and thus commencement of the proposed activities. See, H.R. Rep. No. 95–1474, at 85–86 (1978) (Conf. Rep.). E:\FR\FM\05APP2.SGM 05APP2 19736 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS from its approval would have the potential to significantly affect the air quality of any State. Accordingly, BOEM is not proposing to regulate MSC sources directly, but it would continue its current practice of attributing MSC emissions to the approved facilities that the MSCs support. The most feasible, and perhaps only means, of preventing significant effects on State air quality is to require operators to manage the emissions that are closely associated with its operations. In this rule BOEM is proposing to refine the method for attributing these mobile source emissions to facilities. Historically, and with cooperation from industry, BOEM followed an approach similar to the USEPA’s to account for vessel emissions in the GOM. BOEM’s current regulations require that operators report in their plans those emissions from MSCs that occur within 25 miles of a OCS facility. Although the current regulations are not explicit on this point, BOEM’s GOM practice has been to add these emissions to the emissions of the facility and compare the total against the exemption thresholds to determine whether modeling and controls are required.44 BOEM’s predecessor agencies chose this approach to be consistent with the approach used by the USEPA.45 However there are a number of reasons that attributing all MSC emissions within a 25-mile radius of the facility may not be the best approach. This method of attributing emissions does not provide the most accurate picture of the effects of BOEM’s plan approval on the State’s air quality. Historically, the vast majority of new OCS operations were located within 50 miles of the shoreline. Thus, the 25-mile facility radius adequately addressed the impact of vessel air emissions on the air quality of States. For facilities located within 25 miles of the shoreline, 100% of all MSC emissions would have been accounted for by this formula. For facilities located 50 miles from the shoreline, roughly 50% of the total MSC emissions would have been accounted for. For facilities located 100 miles from 44 The practice has differed in BOEM’s Alaska region during those periods in which the Secretary had air quality jurisdiction over the Arctic OCS. For the Arctic, BOEM’s practice has been to require reporting of MSC emissions in the plan, but the Alaska region has not made it a practice to combine those emissions with the facility’s emissions to compare against the exemption thresholds. 45 See sec. 328 of the CAA, 43 U.S.C. 7627, specifies that ‘‘emissions from any vessel servicing or associated with an OCS source, including emissions while at the OCS source or en route to or from the OCS source within 25 miles of the OCS source, shall be considered direct emissions from the OCS source.’’ OCLSA does not mention emissions from such vessels. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 the shoreline, only 25% of the total MSC emissions would be accounted for and at 200 miles distance, only 12.5% of the emissions would be considered. Also, in terms of the potential impact to a State, the most important MSC emissions generally would be those occurring closest to the State. Therefore, although 25% of MSC emissions for a facility located 100 miles from shore may be accounted for under the 25-mile rule, the 75% of emissions that are not considered would likely have a greater impact. According to the formula used in BOEM’s current exemption thresholds, 3,300 tons of emissions 100 miles from shore would have an equivalent effect to 100 tons of emissions of the same pollutant 3 miles from shore. Applying this formula, the 25% of emissions within 25 miles of a facility would account for less than 2% of the impact on State air quality, and the portion of emissions from MSCs that occur while the MSC is closer to the State’s boundary would have a proportionally larger effect on the State’s air. Historically, facilities in the GOM accounted for the vast majority of the total emissions, with MSC emissions representing only a small share of total emissions. However, in the most recent inventory, BOEM determined that facilities only account for 45% of all OCS emissions associated with oil and gas exploration and production. Also, today, more facilities are being constructed at increasing distances from the shoreline. Today, some are located as far as 200 miles away from shore. Given these shifts, BOEM believes it is no longer appropriate to utilize a blanket 25-mile radius, because that radius does not capture most of the attributed emissions that occur between a port and the facility. Thus, the importance of accurately taking MSC emissions into consideration has grown substantially. BOEM could not ensure that it has avoided permitting uses of the OCS that would adversely affect the State if its evaluation of OCS projects did not take into account the majority of the relevant emissions. Additionally, current BOEM analysis treats all emissions from MSCs as if they originate at the facility itself. Improvements in dispersion modeling technology have made it easier to more accurately project impacts of emissions based on where these emissions actually occur. For this reason, it is no longer necessary or appropriate to aggregate emissions from non-stationary sources at one location for purposes of air quality analysis. Increasingly, lessees and operators are using new types of support vessels, PO 00000 Frm 00020 Fmt 4701 Sfmt 4702 including vessels that operate continuously offshore without having to return to port. When considered along with those support vessels that are unique to the Arctic, either due to its extreme environmental conditions or to the need to make up for the lack of onshore support facilities, it is increasingly evident that the use and types of vessels are substantially different than in the past. In the Consolidated Appropriations Act, 2012 (Pub. L. 112–74), Congress mandated that BOEM regulate air quality impacts from activities on the OCS adjacent to the North Slope Borough of the State of Alaska along with activities on the OCS in the Central and Western GOM. BOEM must now also consider the potential effects caused by air pollution generated by operations unique to the Arctic region, such as ice breakers and other vessels or vehicles that would not normally be necessary or present in the GOM. The relative proportion of attributed emissions to total emissions (i.e., support vessel emissions relative to facility emissions) is substantially higher in Alaska than in the GOM. This is due to, among several things, the substantial differences in the existing oil and gas infrastructure, the significant variations in climate between the GOM region and Alaska, and the relatively greater need for MSCs (and their higher emissions) to support OCS facilities offshore Alaska. In the Alaska region, a typical ratio of MSC emissions to facility emissions would be in the range of 80% to 20%. Thus, the emissions of ice breakers, oil spill support vessels, trucks that operate over ice and other vessels unique to the Arctic make the need to account for MSC emissions even greater than is the case in the GOM. Furthermore, those MSCs used in Alaska are of a type whereby they can more readily operate outside of a 25mile radius of the facility. While supply vessels, crew boats and tug boats cannot easily avoid coming into close contact with the facility they support, this is not true of ice breakers or oil spill support vessels. Such vessels can be and often are located just beyond the 25-mile boundary, sometimes closer to shore than the facility itself. Because, in an Arctic context, the MSCs generate far more emissions than the facilities they support, not accounting for their emissions makes it impossible to appropriately avoid authorizing activity causing or contributing to a violation of the NAAQS. BOEM is proposing a more accurate standard, namely that the emissions of MSCs should be accounted for while they are actually operating in support of E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules the facility. As long as an ice breaker is engaged in active operations on behalf of a facility (and, in whose absence, the ice breaker would not be used), its emissions should count towards the total emissions resulting from plan approval. Once the MSC is no longer providing support to a facility, its emissions should not be considered as part of the projected emissions in the plan. In addition to these differences, technological advances with respect to non-stationary source modeling allow more accurate modeling of emissions from non-stationary sources. Unlike the situation in the past, when there was no accurate means to evaluate the emissions of mobile sources in terms of the impact to stationary sources, such modeling can be readily and accurately done today. BOEM believes that it is important to employ the most advanced and scientifically accurate measurements and evaluation techniques of air pollution, in order to most effectively implement its mandate. For all these reasons, BOEM has reevaluated its historical method of accounting for non-stationary source emissions (i.e., emissions generated from support vessels, vehicles, and aircraft operating on the OCS, or in State waters, that are associated with OCS facilities) and proposes to revise the current practice in both Alaska and the GOM to better address BOEM’s mandate. Instead of automatically applying a 25-mile radius, BOEM is proposing to require lessees and operators to report and attribute the MSCs to facilities to which the vessel is actually providing operational support, regardless of its distance from that facility. In the proposed rule, the key is whether an MSC is operating in support of a facility authorized under OCSLA, not how close the MSC it is to that facility. The proposed rule would require all MSCs operating in support of a facility to attribute their emissions to that facility while they provide such support (except in those rare cases where such attribution would be impractical). MSCs that do not provide support to a facility would not be reported, regardless of how close or distant they are. The discussion of proposed § 550.205(d), in the sectionby-section description below, sets forth the details of how the proposed rule would require lessees and operators to attribute MSC emissions to a facility, including the allocation of emissions from MSCs servicing multiple facilities (see discussion below). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 3. Determination of Attributed Emissions BOEM is proposing to define the term ‘‘attributed emissions’’ to cover nonstationary source emissions associated with a plan, including, ‘‘for any given criteria or precursor air pollutant, the emissions from MSCs and aircraft, operating above the OCS or State submerged lands, that are attributed to a facility.’’ As described in the discussion of proposed § 550.205(d), in section V below, where an MSC described in a plan also supports one or more facilities not described in a plan, the proposed rule would provide several alternatives for determining the emissions from a vessel or vehicle that should be attributed to the particular facility in the plan. A lessee or operator could always choose to attribute all of an MSC’s emissions to a facility regardless of how many facilities it supports. The rule, however, would allow a lessee or operator to attribute only that relevant portion of a vessel’s emissions to its facility or facilities. The proposed rule would provide a lessee or operator with a process to attribute only a portion of an MSC’s emissions to its facility. This procedure is designed to provide the most detailed, accurate information available about the MSC’s emissions. BOEM recognizes that any given lessee or operator may not know at the time of plan submittal, or RUE or pipeline ROW application, the extent to which it will rely on MSCs that also support facilities unrelated to those covered by the lessee’s or operator’s plan. For this reason, the procedure would allow lessees and operators alternative ways of making conservative estimates of the portion of an MSC’s emissions that should be attributed to a facility. The intent of these alternatives is to simplify the process for determining the allocation of support vessel emissions in situations where it would otherwise be impracticable to do so. BOEM’s proposed approach would reduce the potential for over-counting emissions resulting from plan approval compared with BOEM’s current practice. Under BOEM’s current practice, one hundred percent of the emissions of an MSC are counted when located within 25 miles of a plan facility, regardless of whether that MSC also supports five, ten, or even 20 unrelated facilities within a 25-mile radius of the facility. Under the proposed rule, emissions would be allocated to the appropriate facility in all cases where it would be practicable to do so, in accordance with proposed § 550.205(d). Only in the rare situation PO 00000 Frm 00021 Fmt 4701 Sfmt 4702 19737 where there would be no reasonable basis to make any more accurate allocation would the 25-mile radius analysis remain as a last resort option. Ultimately, BOEM believes there is no reason to hold an operator responsible for emissions based on an emitting MSC’s proximity to a facility, but rather it should be required to manage its operations to prevent exceedances of the NAAQS which result from only those MSCs which actually support its operations. Air emissions of an MSC may often occur close to shore, and therefore would cause a greater impact onshore and/or at the SSB, than a similar amount of emissions from that same MSC which occur in the vicinity of the facility. BOEM is seeking comments on this proposed approach and will consider alternative methods that more accurately attribute emissions from mobile sources to the appropriate facility. 4. Exclusion of Aircraft and Onshore Emissions Sources BOEM also proposes to change its approach to accounting for air pollutant emissions associated with other nonstationary sources. The proposed rule would continue to require lessees or operators to identify all vessels and vehicles supporting a facility and to report their relevant air emissions as part of each plan, as is the case with the current policy. However, BOEM is proposing to change how aircraft and onshore emissions would be addressed. Although lessees or operators would continue to be required to identify the likely types and number of support aircraft they propose to use, no collection of emissions data for those aircraft would generally be required under the proposed rule, except in exceptional circumstances. BOEM is proposing this change because collecting information on emissions from aircraft that support OCS operations in all plans would be unduly burdensome since aircraft emissions are a small fraction of emissions in most plans and their inclusion would likely not cause a facility’s projected emissions to exceed the EETs or any AAQSB in a State where it would otherwise not do so. Available data from plans submitted to BOEM and its predecessors indicate that the level of relevant emissions from aircraft is generally an extremely small percentage of the total emissions reported in each plan. Furthermore, there are a large number of aircraft supporting OCS facilities and these aircraft service more facilities and are used for a wider variety of purposes than MSCs, including for purposes other than E:\FR\FM\05APP2.SGM 05APP2 19738 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS supporting oil and gas facilities on the OCS. This makes it cumbersome to accurately quantify and attribute (with respect to OCS support functions) their emissions to individual facilities in a plan in many cases. Accordingly, BOEM believes it is not prudent to require all lessees and operators to report aircraft emissions. The proposed rule, however, would require a lessee or operator to submit aircraft emissions information to account for the situation in which a plan proposes exceptional or unusual aircraft operations. This provision would cover situations in which a lessee or operator plans abnormally high use of aircraft to support its operations, or the lessee or operator plans to use aircraft that emit exceptionally high amounts of pollutants. In those situations, the proposed rule would require the lessee or operator to determine whether aircraft emissions would cause its projected emissions to exceed an emission exemption threshold or AAQSB. If a plan which is already required to conduct modeling results in incremental increases in concentration of a pollutant that are greater than 95 percent of the value of a SIL, the proposed rule would require the lessee or operator to also model its aircraft emissions.46 Likewise, under the proposed rule, lessees and operators would not normally be required to report information on emissions from onshore support facilities. Emissions from large sources onshore are in many cases already identified and regulated by the USEPA, or by the States in the context of their respective SIPs.47 In addition, under the CAA the USEPA has established standards for several types of mobile sources, no matter where they are operated through requirements that engines, vehicles, and equipment be certified to exhaust emission limits, and through the regulation of certain characteristics of the fuels used in these engines. The proposed rule would not require a lessee or operator to gather or 46 BOEM expects that aircraft emissions typically represent less than two percent of all plan emissions, and that any plan with emissions below 95 percent of the value of every SIL, excluding aircraft emissions, would be extremely unlikely to generate total emissions, even if including those from aircraft, in excess of any SIL; therefore, modeling of aircraft emissions would normally not be required. 47 USEPA regulates these sources to the extent they are in source categories subject to New Source Performance Standards (NSPS) or National Emissions Standards for Hazardous Air Pollutants (NESHAP) coverage. States regulate them to the extent they are covered in their State NSPS plans, have taken delegation of NESHAPs, or have chosen to regulate them in order to meet criterial pollutant NAAQS or under NSR. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 report the emissions generated onshore in support of an OCSLA-authorized activity on the OCS. BOEM has determined in the past and continues to hold that, for purposes of this separate program, such emissions are de minimis and that further regulation of them, beyond what already applies or that may be established by USEPA and States under applicable federal and State law, is not warranted. As would be the case with aircraft, however, if a plan describes the use of onshore sources that generate unusually high levels of emissions, such that these emissions could cause the project’s total projected emissions to exceed an EET or AAQSB, then the lessee or operator would be required to provide information on its onshore emissions. While this proposal takes the approach described here for aircraft and onshore emissions, BOEM is considering whether it should instead establish a requirement whereby plans that propose aircraft and onshore emissions above a certain threshold, expressed as either a percent of the total plan emissions or an absolute amount of emissions, would have to include emissions from aircraft and onshore support facilities. BOEM would welcome comments on this approach, and also any data or analysis relevant to the issue of whether, and to what extent, aircraft and onshore emissions should be considered in evaluating a facility’s emissions profile. Please provide comments on this approach and what threshold might be most appropriate. C. Points of Measurement 1. Point-of-Origin Measurement Historically, BOEM applied ‘‘point source’’ modeling to plans for facilities and their MSCs. Point source modeling evaluates all emissions associated with any source as if they originated from a single location, regardless of whether that source is stationary (e.g., a drilling unit or platform) or non-stationary (e.g., a supply vessel). The term ‘‘point source’’ refers to the location from which the pollutants are discharged, not the location at which the impacts from the emissions are measured or evaluated (referred to as receptor locations). In the case of a stationary facility, point source modeling is appropriate because it accurately reflects where the emissions are occurring. With respect to non-stationary sources, however, point source modeling is much less accurate because the actual emissions generated by such a source are discharged over a broad area. BOEM’s regulations currently do PO 00000 Frm 00022 Fmt 4701 Sfmt 4702 not address the appropriate types of models to use to account for emissions from non-stationary sources, although some operators already model nonstationary emissions sources as (1) area or line sources; (2) volume sources; or (3) so-called pseudo-points (i.e., some mobile sources are modeled as if their emissions originated at one or more stationary points).48 MSCs operating in support of facilities on the OCS typically discharge emissions continuously between the port and the facility. BOEM believes line and volume source modeling for non-stationary sources would accurately project the impact of emissions from such MSC on onshore air pollution levels at the SSB. The improved accuracy and information value from line and/or volume source modeling of pollutant dispersions would provide BOEM a more realistic projection of actual impacts on the air quality of a State. With volume source modeling, it is also possible to more accurately model the effect of emissions discharged by non-stationary sources on fixed landscapes (i.e., land, mountains, lakes, etc.), taking into account relevant factors, such as air pressure, currents, winds, and temperatures in relation to the discharge of pollutants and their ambient distribution at distant locations. With improved ambient air quality dispersion data, air quality impacts can be evaluated more effectively. BOEM requests comments on the various types of modeling that could or should be used to more accurately reflect the origin and dispersion of emissions that are generated by mobile sources, such as MSCs, and under what circumstance volume source modeling would be appropriate or inappropriate. 2. State Seaward Boundary (SSB) In developing this proposed air quality rule, BOEM revisited an issue it encountered while drafting its 1980 air quality regulations: Whether air quality impacts should be evaluated starting at the shoreline or at the SSB, which is typically three nautical miles offshore, but which may be as much as nine nautical miles offshore depending on the particular State. On the basis of BOEM’s interpretation of its statutory authority, BOEM has concluded that it is more appropriate to measure at the SSB than at the shoreline. 48 In line-, area-, and volume-source models, the emissions are modeled as if they are emitted evenly and continuously across a line, area, or volume. In point source models, some emissions may be modeled as if they are emitted from many discrete points along a path or over an area. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Section 5(a)(8) of OCSLA requires DOI to regulate ‘‘for compliance with the national ambient air quality standards pursuant to the CAA (42 U.S.C. 7401 et seq.), to the extent that activities authorized under [OCSLA] significantly affect the air quality of any State’’ (43 U.S.C. 1334(a)(8)). BOEM historically interpreted the phrase ‘‘significantly affect the air quality of any State’’ to limit it to considering those effects that would occur landward of the shoreline. BOEM thus historically has evaluated any OCS activity in terms of the effects of that activity on the concentration of pollutants landward of the shoreline. BOEM has re-evaluated this position. BOEM believes the term ‘‘State’’ in section 5(a)(8) of OCSLA should be interpreted to include the entire area of a State’s jurisdiction extending to its seaward boundary (either three or nine nautical miles seaward of its shoreline). (See 43 U.S.C. 1312.) Moreover, the States are responsible for attainment of the NAAQS over the entirety of the State including their submerged lands. The USEPA interprets the CAA consistently with BOEM’s interpretation under this proposed rule. Generally, the USEPA requires States to regulate their air quality up to their seaward boundary. For instance, the USEPA does not allow States to permit an onshore or offshore source that would cause the air quality above State submerged lands to exceed an applicable AAI. In addition, the secondary NAAQS are specifically intended to protect public welfare. Impacts to the air quality above State submerged lands have the potential to adversely affect a range of natural resources, such as marine mammals, coral, fish, etc. that are included in the category of resources protected under the secondary NAAQS. For these reasons, BOEM believes that its regulations should ensure that OCS facilities not cause or contribute to a violation of the NAAQS in any area of a State up to the State’s seaward boundary. The USEPA has advised BOEM that a variety of environmental and scientific studies have shown that changes in air quality have also caused impacts to human health off the coast in near-shore areas. For example, these include specific health impact studies for the NAAQS, as well as port air quality analyses that show the impacts of emissions from ships and diesel engines, diesel emissions studies (health effects and ports)),49 information 49 ‘‘USEPA, Regulatory Impact Analysis: Control of Emissions of Air Pollution from Category 3 Marine Diesel Engines, EPA–420–R–09–019, December 2009.’’ Available at: https://www.epa.gov/ otaq/regs/nonroad/marine/ci/420r09019.pdf. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 regarding environmental justice populations in coastal areas,50 impacts to subsistence fishing on fishing piers that extend into the near-shore areas,51 and the sensitivity of native Alaskan populations.52 There also are studies that trace the emissions from offshore and onshore sources to near-shore and onshore areas. Although the available data are not yet conclusive, BOEM proposes to consider and evaluate the impacts of air pollution over State submerged lands,53 including Alaska.54 Though the proposed rule would impose stricter requirements than exist under the current BOEM regulations, BOEM’s requirements would still differ from those of the USEPA. In accordance with section 328 of the CAA, the USEPA requires, in areas where it has jurisdiction, that any facility located on the OCS within 25 miles of the State 50 See Shell permits for: (1) Kulluk: https://www.epa.gov/region10/pdf/ permits/ocs/shell/kulluk/SoB_Draft_072211_ Public_Comment.pdf, and https://www.epa.gov/ region10/pdf/permits/shell/kulluk/SoB_ Environmental_Justice_Analysis_Kulluk_072211_ Public_Comment_07-19-2011.pd\. (2) Discoverer: https://www.epa.gov/region10/pdf/ permits/shell/discoverer_supplemental_statement_ of_basis_chukchi_and_beaufort_air_permits_ 070111.pdf and https://yosemite.epa.gov/oa/eab_ web_docket.nsf/ Filings%20By%20Appeal%20Number/ 4BB1D10E49B2C0F585257934006FEFB8/$File/ Final%20Attachment%204...11.pdf. 51 Wolfe, R.J. 2004. Local traditions and subsistence: A synopsis of twenty-five years of research in Alaska. Technical Paper No. 284. Alaska Department of Fish and Game, Division of Subsistence, Juneau, Alaska. 52 See Wernham, Inupiat Health and Proposed Alaskan Oil Development: Results of the First Integrated Health Impact Assessment/ Environmental Impact Statement for Proposed Oil Development on Alaska’s North Slope, 2007; and Alaska Native Health Status Report 2009 https:// www.anthc.org/chs/epicenter/upload/ANHSR.pdf. 53 Although there are likely no particular studies that deal with air pollution impacts specifically on the area over State submerged land, the Statement of Basis (SOB) for the Shell permits discusses these concepts as part of the air quality impacts analysis for these permits. These SOBs also have appendices that go into more detail about the air quality impact analysis. 54 Specifically with respect to the Alaskan OCS, the USEPA prepared the following document on the OCS air quality impacts: ‘‘Technical support document review of Shell’s supplemental ambient air quality impact analysis for the Discoverer OCS permit applications in the Beaufort and Chukchi seas,’’ United States Environmental Protection Agency, Region 10, Seattle, Washington, June 24, 2011. See also, https://www.epa.gov/region10/pdf/ permits/ocs/shell/kulluk/SoB_AppA_AQIA_ 072211_Public_Comment.pdf. See also, https://www.epa.gov/region10/pdf/ permits/ocs/shell/kulluk/SoB_AppA_AQIA_ 072211_Public_Comment.pdf. In addition, similar analyses have been done by the USEPA’s Region 4 in connection with the issuance of OCS permits there. The SOB’s in Region 4 are known more generally as preliminary determinations and all can be found at: https://www.epa.gov/region4/air/ permits/ocspermits/ocspermits.html. PO 00000 Frm 00023 Fmt 4701 Sfmt 4702 19739 seaward boundary is subject to all the requirements of 40 CFR part 55. These include, but are not limited to, the federal requirements as set forth in 40 CFR part 55.13 (e.g., NSPS, NESHAPs and permitting requirements) and the federal, State and local requirements of the corresponding onshore area, and the area that is geographically closest to the source or another onshore area that the USEPA Administrator designates (40 CFR 55.14). BOEM welcomes comments and analysis on the potential impacts of emissions generated from OCS sources on the air quality over State submerged lands and/or the potential impact of such emissions on the environment above such lands, as well as any scientific, technical, or other information that can be provided to measure or evaluate the impact of OCSoriginated air pollutants on the area over State submerged lands. 3. Point-of-Impact Measurement Although current BOEM regulations provide that measurements of any potential impacts of OCS emissions take place along the shoreline, they do not specify from which point along the shore the emissions should be evaluated when modeling is required. Because of this, it has generally been assumed the ambient concentrations should be evaluated at the point on the shoreline closest to the facility. This interpretation of the proper approach is reinforced by the formula used for the exemption threshold analysis, which requires operators to calculate the closest distance between the facility and the shoreline. BOEM has published instructions and a guidance document for BOEM forms BOEM–1038 (Gulf of Mexico Air Emissions Calculations for EPs) and BOEM–1039 (Gulf of Mexico Air Emissions Calculations for DOCDs), stating the measurement point (for the purposes of calculating the distance parameter in the emission exemption threshold formulas) should generally be the closest point of land. See BOEM Web site, ‘‘Reporting Instructions,’’ available at https://www.boem.gov/ BOEM-0138-instructions/, and ‘‘Tips to Avoid Common Emissions Spreadsheet Errors,’’ available at https:// www.boem.gov/Form-0138-and-0139Tips/. This approach works well in the GOM, considering wind patterns and other relevant meteorological conditions. In evaluating meteorological data within the parts of the Chukchi Sea OCS bordering Alaska, however, BOEM recognizes prevailing wind patterns are often not from sea to shore (i.e., from north to south) but rather move at an E:\FR\FM\05APP2.SGM 05APP2 19740 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules angle, either from the northwest to southeast or from the northeast to the southwest. Because of this, the point at which the air emissions released from a facility would have the greatest effect (i.e., yield the highest pollutant concentration) may be much farther along the State’s boundary than the closest point on that boundary. In order to accurately model the potential effects of any given air pollutant on a State, therefore, it is important that the effects of such air emissions be evaluated not at the closest point of the State but rather where the concentrations of emissions would be the highest (i.e., where the potential impacts would be the greatest). Because of this, the proposed regulations specify the effects of emissions, for modeling purposes, would be evaluated at those locations in the State(s) where the concentration of any given pollutant is expected to be the highest. Additionally, the effects of emissions would be evaluated in the non-attainment area where the concentration of any given pollutant is expected to be the highest among nonattainment areas for that pollutant (if different from the most affected area). This location might be on land or over State submerged lands. That location in the model would likely be the same for many, but not necessarily all, pollutants. Those air pollutants, such as O3, that are not directly emitted by a facility, but are instead created in the atmosphere, are often more heavily affected by climatological or meteorological conditions, which often cause them to concentrate at a location different than other air pollutants. Given technological advances, BOEM does not anticipate that adding additional hypothetical receptor locations to the modeling should present any technical difficulty but welcomes comments on how this requirement could be implemented most effectively. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 4. Ambient Air Quality Monitoring Monitoring is a general term for ongoing collection and use of measurement data or other information for assessing performance against a standard or status with respect to a specific requirement. In general, there are two basic types of monitoring: • Ambient air quality monitoring, which collects and uses measurement data (or other information) from onshore monitoring stations or remote sensing); and • Emissions source monitoring, which involves collecting and using measurement data (or other information) at individual stationary sources of emissions (i.e., facilities, RUEs, pipeline ROWs, etc.) to VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 verify actual emissions of such sources, and validate the effectiveness of ERM. Thus, ambient air quality monitoring is the systematic, long-term assessment of pollutant levels by measuring the quantity and types of certain pollutants in the surrounding, outdoor air, whereas emissions source monitoring is the process of monitoring particulate and gaseous emissions from a specific source. Air quality monitoring is carried out to assess the extent of pollution, ensure compliance with national legislation, evaluate control options, and provide data for air quality modeling. There are a number of different methods to measure any given pollutant, varying in complexity, reliability, and detail of data. These range from simple passive sampling techniques to highly sophisticated remote sensing devices. In general, monitoring strategies should carefully examine the options to determine which methodology is most appropriate, taking into account the initial investment costs, operating costs, reliability of systems, and ease of operation. Air quality monitoring stations are the most typical means for obtaining ambient air quality information. The locations for monitoring stations may depend on the purpose of the monitoring. Most monitoring networks are designed with human health objectives in mind, and monitoring stations are therefore established in population centers. Many governments (local, regional or national) give specific guidelines on where to monitor within these areas—next to busy roads, in city center locations, or at a location of particular concern (e.g., a school, hospital). Background monitoring stations are also established, to act as a ‘‘control’’ when determining source apportionment. Once data are collected from a monitoring system, they are then stored in data management systems and databases. Subsequently, the data must be retrieved and analyzed to see what they reveal about the effectiveness of regulatory standards, the accuracy of modeling, impacts on health endpoints, and as an overall way of assessing potential impacts. In the U.S. these ambient air quality monitoring data are collected and housed in the Air Quality System (AQS). The AQS contains ambient air pollution data collected by the USEPA, State, local, and tribal air pollution control agencies from thousands of monitoring stations. AQS also contains meteorological data, descriptive information about each monitoring station (including its PO 00000 Frm 00024 Fmt 4701 Sfmt 4702 geographic location and its operator), and data quality assurance/quality control information. BOEM has relied on the USEPA’s AQS data to determine the relevant ambient air quality on which lessees and operators perform their analysis of the AAI’s and the NAAQS in connection with their submission of plans and to comply with BOEM’s air quality requirements in areas under BOEM’s air quality jurisdiction. BOEM has proposed that it should evaluate the air quality of States to the State seaward boundary. There are, however, few monitoring stations in relevant locations on the coast and no monitoring stations in the ocean along the SSB. To improve the accuracy of the estimates of the background concentrations of the relevant pollutants, BOEM is investigating various alternatives for collecting, utilizing and disseminating this information, including technologies such as remote sensing and spectral analysis, and is proposing flexibility to adopt such approaches in the future. The proposed rule would allow BOEM the flexibility to consider adopting such approaches that meet the proposed standard for effectiveness. Otherwise, the relevant background concentrations would be obtained from the relevant USEPA regional office, as is the case today. D. Emission Exemption Thresholds (EETs) Consistent with the current rule, the proposed rule would define EETs as the maximum allowable rate of projected emissions, calculated for each air pollutant, above which facilities would be subject to the requirement to perform modeling. Functionally, these EETs would establish those levels of projected emissions below which BOEM has determined they would not cause or contribute to a violation of the NAAQS or the AAIs. Under the proposed rule, if the USEPA revises a NAAQS, or any applicable SIL or AAI, BOEM would examine the appropriateness of its EETs,55 and, BOEM, at its discretion, would periodically revise its exemption formula(s) or its exemption threshold amount(s) for the corresponding air pollutant(s). Because USEPA has recently revised many NAAQS, the proposed rule would allow revision of 55 The purpose of the EETs is to establish thresholds below which BOEM believes there is no reasonable possibility that BOEM’s approval of a plan would cause a violation of any AAQSB in any State. The EETs are intended to avoid forcing lessees and operators to perform unnecessary air quality modeling in situations where no benefit from such modeling could reasonably be anticipated. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules the exemption formula(s) to reflect these revisions, without waiting for further revisions to trigger a review under this update scheme. The current EETs would continue in place under the proposed rule until the relevant air quality studies have been completed and new EETs, if necessary, are developed and implemented. At a future point in time, but no later than 2020, BOEM will propose new exemption thresholds for the GOM and Alaska OCS Regions by publishing a FR notice. Subsequently after reviewing comments on the notice, BOEM could finalize new exemption thresholds with another FR notice. Consistent with the current rule, the proposed rule provides that, if the projected emissions associated with a proposed facility are exempt, then the lessee or operator would not be required to perform air quality modeling described in proposed § 550.304, or to apply any emission reduction measure(s) (ERM), as described in proposed §§ 550.305 through 550.307. New EETs are not being proposed in this proposed rule because the scientific basis for determining the potential impacts on the States of OCS emissions have not yet been established. The proposed rule, however, would set a new policy governing how BOEM establishes emission exemption thresholds in the future. Specifically, the proposed rule would provide that BOEM would, sometime after the rule becomes effective, publish new proposed EETs in the FR and provide the opportunity for public comment. In the proposed rule, BOEM has included a range of EETs within which BOEM may establish updated EETs for each pollutant. As long as the new thresholds fall within the exemption threshold ranges proposed in this rule, BOEM would not implement them through a separate rulemaking, though the new thresholds would not become final until after BOEM received public comment. If, however, the proposed thresholds were to fall outside these ranges, BOEM would implement them through a separate rulemaking. A range would be established for each criteria or precursor pollutant. The proposed rule would establish both maximum and minimum emissions formulas for each pollutant, above and below which, respectively, BOEM would not set new emissions thresholds without conducting a new rulemaking process. As a result of the new environmental exemption studies, which have previously been described, a new set of formulas will be developed to update the EET formulas currently in place. On an ongoing basis thereafter, VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 BOEM would update the EETs to reflect changes in the NAAQS, SILs, and AAIs; advances in measurement and modeling technology; changes in pre-existing pollution levels in the potentially affected States; and various other factors. The current exemption threshold formulas take the distance of the facility from the State into account because dispersion modeling would indicate the impacts are likely to be lower as the distance involved becomes greater. The proposed formulas for these minimums represent emissions levels below which the ambient air impact at the nearest point in a State would not exceed any SIL, taking distances into account. However, there may be a more appropriate manner in which to establish the minimums. For that reason, BOEM requests comments on the EET formulas and the underlying analysis used in this rulemaking or whether absolute values may be more appropriate. Until such time as BOEM has determined new EETs and has published them in the FR (‘‘the date of the Notice’’), the distance component of the emissions exemption calculation would continue to be the distance of the facility from shore. After the date of the Notice, each distance formula would instead utilize the distance of the facility from the SSB. After the date of the Notice, the lessee or operator would be required to apply the new set of formulas for the EETs in effect at that time (i.e., to determine whether projected emissions would be exempt from further analysis). BOEM would use the following criteria to determine the EET formulas: The absolute level of projected emissions; the distance of the proposed facility or facilities from any State or from critical natural resources, animals, fish and habitats; the relative need to protect public health and welfare and the existing amounts of air pollution in potentially affected States; the types, frequency and duration of any air pollutant emissions and their formation and/or dispersion characteristics; prevailing meteorological characteristics; any USEPA AAQSB applied in this proposed rule; other facilities and vessels located in the vicinity of the proposed facility; and other necessary and appropriate considerations. Until BOEM has established new formulas based on these criteria, the proposed rule would provide that projected emissions are exempt if they are below the current exemption formulas. The intent of those provisions that would allow BOEM to modify the EETs is to ensure that the exemption thresholds accurately reflect the PO 00000 Frm 00025 Fmt 4701 Sfmt 4702 19741 amounts of potential emissions that could adversely affect a State. Because the NAAQS are subject to change as scientific knowledge improves and because modeling techniques and methods may improve over time, the emission exemption threshold formulas should also be subject to change. Under the proposed rule, BOEM would revise the EETs on an ongoing basis either as a result of a change in an applicable standard or because BOEM’s ability to measure and evaluate the impact of existing EETs has improved. E. Emissions Reductions Measures (ERM) 1. Emissions Credits and Offsets Current regulations specify that BACT should be implemented as the first and primary emissions control mechanism any time that a proposed facility is estimated to exceeded a SIL. This BACT requirement was meant to ensure consistency with the USEPA regulations as they existed when the regulations were issued in 1980. BOEM’s rationale regarding this point has evolved to allow for greater flexibility, while still protecting the air quality of neighboring States. Under the proposed rule, if the projected emissions associated with a proposed OCS facility exceed an AAQSB, operational controls would be the first option to be considered. Operational controls, such as limiting the hours of operation or operating at a higher level of engine efficiency could be both more cost effective and more successful in reducing incremental emissions, particularly in those situations where the proposed exceedances are small. As an alternative, lessees and operators would have the option of replacing old or inefficient equipment with newer and less polluting equipment. This could involve, for example, replacing a diesel engine with a natural gas powered engine. If these options were not sufficient, other ERM, including BACT and emissions credits, would then be considered.56 One change in this regard relates to emissions credits. Under the current rule, offsets can only be used once the relevant BACT has been deemed inadequate. Even then, the current rule provides no guidelines as to how offsets might apply in situations other than to offshore facilities. Other forms of emissions credits, such as emissions trading, acquiring of trading program 56 The BOEM provision allowing for equipment replacements is contingent on the lessee or operator complying with all other applicable federal regulations, as noted in the proposed regulation in section 550.309(f). E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19742 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules allowances and so forth, are not addressed by the current regulation. Under the proposed rule, emissions credits, which would include offsets, are defined as: ‘‘Emissions reductions from an emissions source(s) not associated with the plan that are intended to compensate for the excessive emissions of criteria or precursor air pollutants, regardless of whether these emissions credits are acquired from an emissions source(s) located either offshore or onshore, including: (1) Emissions offsets generated by the lessee or operator directly; or (2) emissions offsets acquired from a third party; or (3) trading allowances or other alternative emission reduction method(s) or system(s) associated with a marketbased trading mechanism, such as a mitigation bank, or through other competitive markets where these assets are exchanged.’’ Essentially this means that emissions credits consist of any form of emissions reduction, regardless of whether such reductions consist of physical or operational controls on nonplan facilities (i.e., facilities other than those covered by the proposed plan), or whether they consist of the use of market-based mechanisms that involve reductions achieved through third parties. Under the proposed rule, emissions offsets could consist of BACT applied by a lessee or operator to another one of its own, previously approved, facilities on the OCS. The proposed rule would therefore considerably increase the mechanism by which emissions reduction could be achieved. Under the proposed rule, in cases where operational controls would not be sufficient to achieve the required emissions reductions lessees and operators would be able to utilize emissions credits, as opposed to applying BACT to a facility in the proposed plan. The proposed rule would also provide that lessees or operators who submit plans that include emissions credits demonstrate that the operator has notified the relevant State and that emissions credits be verifiable. The selection of emissions credits in lieu of BACT would often result in both a net cost savings and a net environmental benefit. The savings would result from the greater flexibility afforded lessees and operators to make the reductions either on their facility, on another facility (either on the OCS or in waters above State submerged lands), on some unrelated stationary emissions source onshore, or through acquiring the emissions credits from a third party. Because older, higher polluting facilities whose emissions would be easiest to reduce are most frequently located on or VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 near the shoreline, in most cases the use of emissions credits would involve a reduction in the emissions from an onshore stationary source or from an older oil and gas facility located offshore in waters above State submerged lands. Under the current regulations, offsets are only permitted if they would cause a reduction of emissions on the OCS with respect to the facilities covered by the proposed plan. Under the proposed rule, any reduction in emissions that is accomplished within the same USEPA air quality control region (AQCR) 57 would be an acceptable emissions credit. Thus, if a facility associated with a proposed plan were required to reduce its emissions by 100 tons of NOX per year, such a reduction could be generated from any other source within the relevant AQCR, whether the source of that reduction is located on the OCS, over State submerged lands, or onshore, and regardless of whether the source of the reduction is stationary, such as a facility, or mobile, such as an MSC. As currently defined, the AQCR boundaries do not extend to include the OCS and, for this reason, it may sometimes be difficult to determine which AQCR would be most applicable. BOEM also recognizes that some AQCRs are very large, so it may not be certain that offsets in one part of the AQCR have a benefit to the area affected by offshore emissions. BOEM requests comments on how to best to define the relevant AQCR(s) and on whether there may be more appropriate alternative to defining the offset-generating areas or how to best refine the approach of applying AQCRs in this context. The use of emissions credits in lieu of BACT would provide a net environmental benefit because the use of emissions credits would typically involve a reduction in emissions onshore or over State submerged lands, at that point where the impact to State air quality is greatest, rather than on the OCS, which might be far away from the point at which any impact might be felt. For example, if an OCS facility located 30 miles offshore were to be required to reduce its emissions of NOX by 200 tpy, under the current regulations that reduction would have to be achieved primarily by reducing the emissions from the facility itself. As a result, the 200 TPY reduction in NOX emissions 57 An air quality control region (AQCR) is an area, designated by the USEPA, that has common air pollution issues and which is likely to be affected by the same sources of air pollutant emissions. See 42 U.S.C. 7407. The term AQCR is defined at 40 CFR 51.100(m) and in 40 CFR 60.21(i). The current AQCRs are defined in the USEPA regulations at 40 CFR part 81 subpart B. PO 00000 Frm 00026 Fmt 4701 Sfmt 4702 from an OCS source might avoid the same amount of ambient NOX at the shoreline that would be avoided by only 20 TPY reduction in emissions at the shoreline. Given the greater flexibility provided by the proposed rule, if a lessee or operator instead decided to instead pay an onshore power plant to reduce its emissions by the same 200 TPY of NOX, the net impact to the State would be a reduction in onshore emissions of 200 TPY. Thus, the same reduction in NOX emissions could have a much greater positive environmental impact. For more details on the offset requirements, see the section-by-section analysis for section 550.309(e). Furthermore, because the proposed rule does not prohibit the joint acquisition of emissions credits, the proposed rule would allow emissions credits to be obtained and divided among multiple lessees or operators (presumably located near to one another in the vicinity of a State) in order to potentially spread the costs of complying with air quality requirements. 2. Applicability of Best Available Control Technology (BACT) Upon an Exceedance of the Significant Impact Levels (SILs) BOEM’s current regulations require that any proposed plan that identifies projected emissions of air pollutants that would result in an exceedance of the SILs onshore is required to implement BACT (30 CFR 550.303(g) and 303(h)). Under existing BOEM regulations, ‘‘Best available control technology’’ or BACT means an emission limitation based on the maximum degree of reduction for each air pollutant subject to regulation, taking into account energy, environmental and economic impacts, and other costs. The BACT is required to be verified on a case-by-case basis by the Regional Supervisor and may include reductions achieved through the application of processes, systems, and techniques for the control of each air pollutant. Under the proposed rule, the evaluation of the SILs would not automatically trigger the requirement for BACT. In fact, BACT would never be the only possible ERM. Under the proposed rule, emissions credits including offsets would always be available as an alternative. The proposed rule would generally limit the requirement to apply BACT and/or offsets (or, more generally, emissions credits) to situations where the SILs exceedance relates to a nonattainment area. For a long-term facility whose emissions affect only attainment areas, BACT and/or offsets would be E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules required only if a further analysis indicates that the SIL exceedance, taken in combination with all other facilities located in the same general vicinity, would potentially cause an increase in the concentrations of a relevant air pollutant that would endanger the attainment status of some area in any State by exceeding the AAIs. In all other cases, when the AAIs are not exceeded, the proposed rule would not generally require further ERM. For long-term facilities whose emissions affect a non-attainment area, where an exceedance of the relevant SILs would trigger the requirement for more extensive controls, BOEM expects that lessees and operators would likely choose emissions credits in all but a few cases (likely limited to those rare situations where localized control equipment would be the only effective way to prevent the facility from adversely affecting the attainment status of an onshore area). asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 3. ERM Evaluation Criteria If the modeling results show impacts that are higher than the SILs, ERM would be required as specified in § 550.306, for a short-term facility, or as specified in § 550.307, for a long-term facility. Current BOEM regulations require that any operator subject to controls (because its emissions are projected to exceed the SILs as defined in BOEM’s regulations) must conduct a BACT analysis, and that BOEM must evaluate the amount of emissions reductions that each available emissions-reducing technology or technique would achieve, as well as the energy, environmental, economic and other costs associated with each technology or technique. The current regulations do not, however, specify explicitly that each lessee or operator evaluate all the potentially effective forms of BACT and do not therefore require a consideration of all the feasible alternatives. This section describes the methodology in this proposed rule for determining what forms of ERM would be required for any given plan. Under the proposed rule, a lessee or operator would be required to identify all of the potentially feasible forms of ERM and rank them according to their potential effectiveness. Only those situations where a potentially more effective ERM is infeasible 58 would 58 In the case of BACT, the cost effectiveness of every option must be considered and any alternative that is not cost effective (in terms of the emissions reductions achieved) may be excluded as non-viable. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 such an operator be allowed to propose less potentially effective forms of ERM. The proposed rule would provide a two-stage procedure for analyzing and selecting ERM, when required, based on modeling results. First, the lessee or operator would identify all the alternative control technologies available and determine their technical feasibility. Second, the lessee or operator would rank and choose specific control technologies. Although these two stages are implicit in BOEM’s current regulations, they are stated explicitly for the first time in this proposed rule. The purpose of this approach would be to ensure that the types of ERM considered would be those that would have the greatest potential to reduce the amount of emissions. The first stage in the process would require lessees and operators to consider all technically feasible control technologies (and not submit a plan that fails to mention feasible options). No lessee or operator could propose only control technologies that would either be largely ineffective (but inexpensive to implement) or cost prohibitive (so they could be discarded) to avoid selecting a cost effective and technologically effective form of ERM. The second stage would require operators to demonstrate the selected ERM is the most effective control technology that could be implemented cost effectively. Under the proposed rule, the most effective technology would always be considered, so it would be implemented unless it was found not to be cost effective. The effectiveness of any given form of ERM would be measured in terms of the total number of tons of a pollutant that would be reduced on an annual basis. The cost effectiveness would be the annual tonnage reduction estimate divided by the cost. Thus, cost effectiveness would represent the cost per ton of pollutant emissions averted through the application of ERM. Both the amount of emissions reduced and the cost effectiveness of any proposed or potential ERM can be evaluated for any given pollutant or based on the total reduction in all relevant pollutants, depending on which pollutants need to be reduced. Determining cost effectiveness would require considering the benefits to be achieved from emissions reductions against the costs that would be incurred to achieve those benefits. Accordingly, cost effectiveness means the absolute effectiveness of the technology (in terms of tons of emissions avoided), and its emission control efficiency (ECE) (percentage reduction) compared to the total potential cost of the technology. PO 00000 Frm 00027 Fmt 4701 Sfmt 4702 19743 All of the costs and benefits of any potential control would be considered in determining what constitutes a cost effective emission reduction measure and what would, therefore, constitute viable ERM. Although not stated explicitly, the current regulations allow a lessee or operator to apply no controls whatsoever when its ‘‘proposed’’ BACT is claimed to be unfeasible. The proposed rule would make explicit that technically feasible controls would always be required but would allow much greater flexibility in how the relevant ERM are determined and evaluated. Once the required emission reduction measure(s) (ERM) are identified, a lessee or operator would be required to thoroughly describe the emissions reduction controls it proposes to apply. The rule would also provide specific provisions governing the sufficiency and effectiveness of these measures and require a lessee or operator to monitor its continual effectiveness over the duration of the plan under reasonably foreseeable circumstances. The proposed rule would also explicitly articulate requirements for ERM that are implicit in the current regulations. The proposed rule would retain the term BACT, though the definition would be rewritten for clarity. In maintaining a ‘‘performance-based’’ approach to the proposed rule, BOEM is not proposing specific types of BACT, technical standards, or ERM. BOEM is seeking comment on whether it should identify various forms of ERM that have been approved in other situations, whether by BOEM, the USEPA or another regulator, and whether BOEM should provide additional specificity on how to determine the most appropriate form of ERM and/or what cost effectiveness would be considered presumptively reasonable in making such a determination. All of these issues could be addressed in the context of establishing criteria for what may constitute ‘‘presumptive BACT’’ or presumptive ERM. BOEM invites comment on whether BOEM should adopt presumptive ERM and, if so, what processes it should use for adopting and updating the various forms of presumptive ERM that are suggested or approved. Section III of USEPA publication entitled ‘‘PSD 59 and Title V Permitting Guidance for Greenhouse Gases,’’ [Office of Air Quality Planning and Standards, Air Quality Policy Division, Research Triangle Park, NC, EPA–457/ 59 PSD stands for Prevention of Significant Deterioration. E:\FR\FM\05APP2.SGM 05APP2 19744 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules B–11–001, March 2011] describes the USEPA’s process for determining the appropriate use of BACT.60 BOEM has examined the USEPA approach and intends to take these guidelines into consideration in developing its own guidelines for ERM, as well as for making a determination as to the viability and cost-effectiveness of alternative forms of ERM ‘‘taking into account energy, environmental, and economic impacts and other costs.’’ Because BOEM intends to publish its own ERM guidelines, it solicits comments on the USEPA’s approach and the underlying methodology for making the determination as to what forms of ERM may be most appropriate under various circumstances, as well as comments on why or under what circumstances the USEPA approach may or may not be appropriate to the OCS environment and how the ERM requirements could be best tailored to the unique conditions of the offshore oil and gas industry. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 4. Nitrogen Oxides (NOX) Waiver and Volatile Organic Compounds (VOC) Waiver There are situations where the increase in a given precursor pollutant will not contribute to an increase in the ambient air concentration of the CP for which it is a precursor. That situation is particularly important in the case of NOX and VOCs, which are both precursors for O3. The USEPA has recognized that, under certain circumstances an increase in NOX or VOC may have no effect on the formation of O3 in the tropospheric atmosphere and may, in fact, actually cause a decrease in O3 formation. The degree to which a change in the emissions of NOX or VOCs would contribute to O3 formation in the atmosphere is referred to as the O3 efficiency. Because there are situations where an increase in NOX or VOCs would have no negative or even a positive effect, BOEM is proposing to exempt a facility from reducing its 60 BOEM and the USEPA differ in their requirements for BACT, primarily due to the difference in their respective regulatory frameworks. BOEM reviews the BACT alternatives as part of its AQRP, under both the current regulation and the proposed rule prospectively, determining in advance of the facility installation what form of BACT is appropriate. The USEPA also evaluates BACT prospectively, but the CAA also specifies, among other requirements, that BACT cannot be less stringent than any applicable standard of performance under the New Source Performance Standards (NSPS) (42 U.S.C. 7479(3)). Therefore, although BOEM looks to USEPA practices when evaluating control technologies, due to the unique nature of the OCS, BOEM also exercises independent judgment on what constitutes BACT and how it should be applied. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 emissions of these precursor air pollutants in such situations. Generally, VOC emissions must be greater than NOX emissions to trigger O3 formation. A ratio of VOCs to NOX of 4:1 to 16:1 is within the range where O3 forms.61 The USEPA allows the issuance of a ‘‘NOX Waiver’’ for areas where limiting NOX emissions does nothing to decrease O3, and in some cases, can actually increase O3. A ‘‘VOCs Waiver’’ could similarly be issued in the reverse case (i.e., where there is already too much VOC in the atmosphere to further contribute to the production of O3). The proposed rule would adopt a similar approach and limit the mandate to reduce NOX and VOC emissions, for the purpose of limiting O3 formation, to those situations where the limits would be effective. Because atmospheric conditions change over time, the rule would also propose that, in the event that a facility is waived from controlling NOX as a precursor to O3, or from controlling VOCs for controlling O3, BOEM could re-impose the requirement to set up ERM at some future date, if BOEM determined that the waiver was not having the intended effect. F. Consolidation of Emissions From Multiple Facilities The proposed rule would require a lessee or operator to combine projected emissions from its multiple facilities under certain circumstances in order to evaluate whether the close placement of multiple facilities operating at the same time could jointly cause or contribute to a violation of the NAAQS. This proposed requirement would only apply to facilities that are wholly or partially owned, controlled or operated by the same entity, and is designed to prevent a single entity from segmenting its operations into multiple plans to avoid exceeding EETs. Emissions from nearby facilities that are not wholly or partially owned, controlled or operated by the same entity would be reviewed in the context of the relevant NEPA analyses. BOEM’s current practice is to require, in specific circumstances, the consolidated analysis of facilities covered by multiple plans in accordance with the following provision of § 550.303(j): ‘‘If, during the review of a new, modified, or revised Exploration Plan or Development and Production Plan, the Regional Supervisor determines or an affected State submits information to the Regional Supervisor 61 This topic is addressed in more detail in the book ‘‘Introduction to Atmospheric Chemistry,’’ by Daniel J. Jacob, Princeton University Press, 1999, available at the following location: https:// acmg.seas.harvard.edu/people/faculty/djj/book/ bookchap12.html. PO 00000 Frm 00028 Fmt 4701 Sfmt 4702 which demonstrates, in the judgment of the Regional Supervisor, that projected emissions from an otherwise exempt facility will, either individually or in combination with other facilities in the area, significantly affect the air quality of an onshore area, then the Regional Supervisor shall require the lessee to submit additional information to determine whether emission control measures are necessary.’’ The current regulations do not specify under what circumstances the Regional Supervisor would make such a determination. This proposed rule recognizes the fact that the emissions from two or more OCS facilities located in close proximity to one another may have an adverse impact on the air quality of a State even if the individual EETs, considered separately, would indicate that that facility should not cause an adverse impact to the air quality of a State. This would generally only be true in the situation where two or more facilities were operated contemporaneously, however. Closely-grouped facilities that emit pollutants at the same time can affect the air quality of a State differently than facilities that are spread across a larger area because the emissions would be more concentrated and would, correspondingly, cause a greater concentration of air pollution within a neighboring State. Accordingly, the proposed rule would require consolidation to prevent a lessee or operator from ‘‘segmenting’’ his operations by describing proximate activities in separate plans or RUE or pipeline ROW applications in order avoid modeling or applying controls. The proposed rule would specify that a lessee or operator would be required to consolidate projected emissions from multiple facilities if: (1) The emissions from multiple facilities are generated by proximate activities (i.e., the same well(s); a common oil, gas, or sulphur reservoir; the same or adjacent lease block(s); or, by facilities located within one nautical mile of one another); (2) the lessee or operator wholly or partially owns, controls or operates those facilities; (3) the construction, installation, drilling, operation, or decommissioning of any of the lessee or operator’s facilities occurs within the same 12-month period as the construction, installation, operation, or decommissioning of another facility that meets conditions 1 and 2; and, (4) such a consolidation of emissions from multiple facilities would generate emissions sufficient to exceed an applicable emission exemption threshold. If two or more facilities meet all of these conditions, under the proposed rule, the lessee or operator E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS would be required to calculate the sum of the projected emissions from those facilities (including its respective attributed emissions). The proposed rule would specify that, if all of the emissions to be combined relate to the lessee’s or operator’s wholly-owned facilities, the lessee or operator would be required to provide the data and analysis regarding the complex total emissions. However, where the lessee or operator only partially owns the facilities whose projected emissions are to be consolidated, the lessee or operator would need to gather data from the operator of any facility that it does not wholly own 62 or which it does not operate and would need to provide to BOEM all the data and analysis it gathered. BOEM would make a determination that the lessee or operator has appropriately considered the relevant data in its analysis of the complex total emissions. Under the proposed rule, if any lessee or operator is required to consolidate projected emissions data from multiple facilities, then anywhere a requirement applies to projected emissions, the lessee or operator would instead be required to use complex total emissions (except with respect to the process by which projected emissions are determined for any given facility, as specified in § 550.205(d)). G. Ongoing Monitoring and Review of Projected Emissions BOEM is proposing mandatory record keeping of fuel usage and activity data for all emissions sources, and we are proposing that non-exempt facilities subject to emissions reductions controls or mitigation and facilities that are exceptionally large be required to monitor their actual emissions. BOEM expects that most of the monitoring that would be required to be implemented in connection with the proposed rule would be of the type known as a Predictive Emissions Monitoring System (PEMS).63 PEMS is an air quality monitoring that provides continuous data recording and generates reports according to the applicable regulatory requirements. PEMS is used to meet 40 CFR part 60, appendix B, requirements for audit and performance standards on new stationary sources. It is also applied in 62 All BOEM plan approvals and data are publically available and can be obtained from the BOEM Web site. 63 For an overview of PEMS as well a general background discussion of other monitoring systems that may also be appropriate in certain contexts on the OCS, see citation to this Web site: https:// cfpub.epa.gov/oarweb/mkb/Basic_Information.cfm. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 many other contexts, including the PSD program (40 CFR 51.166 through 51.166), and the approval and promulgation of implementation plans (under 40 CFR 52.21). The USEPA generally regards PEMS as a secure and reliable means of collecting, storing, and reporting compliance data. PEMS can be used on most combustion sources that fire gaseous or liquid fuels and for most compliance parameters such as NOX, SO2, CO, CO2, O2, hydrocarbons, NH3, hydrogen sulfide, and formaldehyde. BOEM welcomes comments on the potential application of PEMS and/or the best approaches for selecting and evaluating monitoring systems. 1. Recordkeeping and Measurement Criteria In order to ensure ongoing compliance with the NAAQS, the proposed regulations would authorize BOEM to collect additional information on activities or plans after they have been approved. Under the current structure, BOEM approves all plans for facilities in advance of the construction and installation of such facilities on the OCS. With respect to air quality, the plans contain estimates of prospective pollutant emissions based on the information that is available about the most likely emissions for every emissions source that is proposed to be used. This process necessarily involves estimates because it utilizes emissions projections for equipment, much of which is not yet in use at the particular site. The same principle applies to proposed ERM. The ERM that are put into the plan are also prospective; the ERM would not be applied to the facilities, equipment or MSCs until after a plan has been approved. The effectiveness of any physical controls that have not yet been installed cannot be measured but only projected. Based on this approach, it would be difficult to determine what the actual emissions would be for one facility, on a standalone basis, let alone a range of support vessels, vehicles, aircraft and ancillary equipment. For this reason, namely, in order to provide greater confidence that the actual emissions levels are not exceeding the projected levels, BOEM has proposed a more reasonable approach to establish basic recordkeeping and measurement criteria that could be applied after a plan has been implemented and the associated facilities are fully operational. The proposed rule adds a requirement that all operators (1) keep fuel logs for all the relevant equipment and (2) maintain operating records (e.g., PO 00000 Frm 00029 Fmt 4701 Sfmt 4702 19745 operating times by level of capacity) for all key facilities, MSCs, and equipment described in the proposed plan. The information would need to be maintained on a month-by-month basis and would need to be provided to BOEM according a schedule determined by the respective BOEM region. In addition to requiring all facilities to keep records as described above, certain facilities would also be required to measure actual emissions at specified intervals. The proposed rule outlines four criteria that would be used to determine which facilities would be subject to this requirement. First, the proposed rule would require the measurement of air pollutant emissions for plans which are approved subject to BACT. Such plans would have to demonstrate their actual emissions were not significantly above the projected emissions. Second, the proposed rule would require that any facility or emissions source that is not certified or compliant with USEPA emissions requirements applicable to engines or equipment intended or certified for use in the U.S. should also be required to demonstrate that its levels of actual emissions nevertheless are consistent with the estimates provided in the plan. Because the equipment is not certified, it is impossible to know without actual measurement the extent to which emissions are similar to emissions from certified equipment. Accordingly, BOEM believes that a demonstration should be made that the actual emissions of such equipment complies with the emissions levels which BOEM approved as part of the plan review. Third, there are some situations where the accuracy and reliability of estimates of projected emissions, based on emissions factors, are unreliable or would be subject to a great range of variation. BOEM proposes to require measurement and reporting of actual emissions for plans in which the projected emissions cannot be reliably determined or in situations where the potential error in the emissions factors could result in a significant underestimate of the projected emissions (particularly in situations where the underestimate is of such a magnitude that not addressing the error could have a significant impact upon a State’s air quality). This requirement is intended to allow BOEM to require monitoring on facilities with high emissions or a high level of variability in the accuracy of emissions factors or estimates. Because projected emissions are based on an activity rate and an emissions factor and because emissions factors are somewhat uncertain, the difference between the projected E:\FR\FM\05APP2.SGM 05APP2 19746 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules emissions and actual emissions will increase with higher activity rates. So, the range of potential projected emissions for larger facilities is much greater than those for smaller facilities, and the potential ramifications for errors are larger than for small facilities. Although this provision would likely be rarely invoked, it is important that BOEM can verify the actual emissions of large facilities in situations where it has evidence to believe that the actual emissions are under-reported. Finally, in some areas, particularly those where the background concentrations of a pollutant are high or where the USEPA has recently changed a standard, and where there is a greater likelihood of a nearby facility causing or contributing to a violation of the NAAQS, monitoring of actual emissions may also be required. The modeling that was used to demonstrate that there is, presumptively, no such impact could only be valid if the assumptions regarding the actual background concentrations of pollutants are accurate. If a model of potential emissions were to rely on inaccurate background concentration estimates, its conclusions would also be suspect. For that reason, BOEM has proposed that these facilities in these areas may also be required to verify that their emissions correspond to those estimated in the plan. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS H. Structure of the Proposed Rule In contrast with the current BOEM regulations, where air quality data provisions are set forth in many sections, including §§ 550.215, 550.218, 550.224, 550.225, 550.245, 550.249, 550.257, 550.258, and 550.284, the proposed rule would establish one set of data requirements related to air quality in a new § 550.205. In the current regulations, plan requirements applicable to EPs are dealt with in one part of the regulations, and plan requirements applicable to DPPs and DOCDs are dealt with in another part of the regulations. Because the air quality requirements applicable to EPs, DPPs, and DOCDs are largely the same, BOEM proposes to place all the plan requirements relevant to air quality in one consolidated section. The majority of the proposed rule consists of two major parts: A new section on data requirements and collection, § 550.205; and an air quality analysis control and compliance subpart, 30 CFR part 550 subpart C. The content of the two primary air quality data sections from the current regulations, § 550.218 and 550.249, would be covered by proposed VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 § 550.205, and those existing sections would be eliminated. The proposed rule would replace the current subpart C, which includes air quality evaluation and analysis and requirements for the application of emissions reductions measures. This new proposed subpart would describe the process for post-approval review of plans and for addressing compliance with future changes to the AAQSB on the part of the USEPA. BOEM is proposing to change the title of subpart C from ‘‘Pollution Prevention and Control’’ to ‘‘Air Quality Analysis, Control, and Compliance,’’ to better reflect the scope and intent of this subpart. To make the regulations more precise and to ensure they remain up-to-date, BOEM is proposing to add a number of new definitions and to clarify a number of existing definitions. The proposed rule would consolidate all the definitions and acronyms specific to air quality in a single section, replace or update various provisions, and clarify the regulations in those circumstances where the existing text could be considered unclear or potentially subject to more than one reasonable interpretation. 1. Potential Monitoring Alternatives BOEM solicits comments on various alternatives that could be used to achieve the Bureau’s objective of monitoring large emitters. The following are examples of alternatives that have been identified. In addition, there may also be other alternatives that should be considered. One alternative would be for BOEM to require measurement of actual emissions on facilities with emissions above a specific threshold to be determined in the final rule. BOEM would like comments on what an appropriate threshold might be. A second alternative would be for BOEM to establish general criteria that could be used to determine the potential error in the emissions estimates. Among the criteria being considered are: Production volume of the facility, size, type, and efficiency of engines proposed to be used, the age of equipment, the attainment or designated nonattainment status of the nearby areas within any State, the length of time the equipment will be operated, the proximity to other facilities, and/or the historic reliability and variability of emissions factors for the equipment being used. Under this alternative, BOEM would make a determination on a case-by-case basis whether any given facility would be required to report its actual emissions. PO 00000 Frm 00030 Fmt 4701 Sfmt 4702 A third alternative would be to require actual emissions measures for any plan that proposes to use equipment with emissions factors that BOEM has determined to be particularly unreliable. Under this alternative BOEM would provide information to lessees and operations as to what specific types of equipment would be subject to this reporting requirement. The fourth alternative would be to establish a monitoring and reporting formula whereby facilities whose projected emissions exceed a fixed percentage of the emission exemptions thresholds would be required to monitor and record their actual emissions. For example, BOEM could require that any facility with projected emissions for any CP that exceeds 85 percent of the threshold would have to report its actual emissions for all criteria and major precursor pollutants. This is due to the potential margin of error in the emissions factors. BOEM solicits comments on the appropriate percentage of the emissions exemptions thresholds for this reporting threshold. A fifth alternative would be any combination of the previous alternatives. BOEM is also considering whether it should require measurement of actual emissions from activities in all plans, but limit the kinds of sources for which measurement is required, based on the uncertainty in the emissions factors estimates for specific pieces of equipment and the potential costs of measuring emissions from the associated equipment. The section-bysection description of proposed § 550.311 sets forth text for this proposal. In addition to monitoring requirements, BOEM is also proposing provisions that clarify the way in which BOEM will ensure that previously approved plans comply with the statutory requirements. As noted previously, OCSLA requires ‘‘compliance with the national ambient air quality standards pursuant to the CAA (42 U.S.C. 7401 et seq.), to the extent that activities authorized under [OCSLA] significantly affect the air quality of any State’’ (43 U.S.C. 1334(a)(8)). BOEM believes this provision should properly be interpreted to mean that BOEM has a continuing obligation to ensure the protection of State air quality and that such obligation extends to ensuring compliance with the NAAQS, as they are amended to incorporate new and more accurate scientific information regarding the potential adverse public health and welfare impacts of air pollution. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Because the NAAQS are updated periodically to reflect improved information, BOEM believes that it would be appropriate to re-evaluate plans or RUE applications approved many years ago for compliance with section 5(a)(8) of OCSLA, even though the facility has not been modified in such a manner as to require the submission of a revised plan. For this reason, in addition to the new recordkeeping and emissions measurement requirements, BOEM is also proposing that lessees and operators be subject to a requirement to resubmit their plans on a periodic basis for re-evaluation. The current practice, and one that would be continued under the proposed rule, is to project air emissions for ten years from the date of plan submission. Under the proposed rule, if a lessee or operator is operating under an approved plan, it would be required to resubmit a plan for a periodic air quality review ten years after BOEM’s previous approval of the operator’s last plan. This provision would be added in furtherance of the objective of section 5(a)(8) of OCSLA, which requires BOEM to ensure compliance with the NAAQS, and which makes no provision for any exceptions with respect to previously approved plans. All of the applicable requirements of this subpart in effect on the date of resubmission would apply on the same basis to a resubmitted plan as for an initial plan or RUE application. BOEM requests comments on this provision, particularly with respect to the potential impact on lessees and operators. 2. Plan Resubmittals Once the new EETs have been established, BOEM would conduct periodic reviews of plans that were approved prior to that time. This is to ensure the lessee or operator’s emissions remain compliant with OCLSA and are in accordance with the provisions of the OCS leases that require compliance with subsequent revisions to the regulations. Plans would be resubmitted according to the schedule in proposed § 550.310(c), no more frequently than ten years after they were approved. Plans that were revised or modified would also be due for resubmittal ten years after their most recent revision or modification was approved. A plan resubmitted pursuant to this proposed provision would be required to be updated to comply with the requirements of § 550.205 as they exist at the time of the plan resubmission and to include the most current data on emissions factors. It would be reevaluated against the EETs and formulas as they exist at the time of the VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 plan resubmission. The resubmitted plan must be modified to include any data collected on actual emissions since the last time the plan was submitted or resubmitted. Under the proposal, if a plan would indicate an exceedance of any applicable emission exemption threshold, all of the other applicable requirements of this subpart would apply as for an initial plan. For plans that were approved prior to the effective date of this rule, the lessee or operator would be required to resubmit the air quality component of its previously approved plan after the date in which BOEM has determined new EETs and published them in the FR. The resubmission would be conducted on a phased basis, beginning in 2020. For further details, see the section-by-section analysis description of proposed § 550.310(c)(2). I. Gulf-Wide Offshore Activities Data System (GOADS) The proposed rule would include a new provision to support BOEM’s effort to inventory emissions on the OCS. Currently, BOEM maintains this type of emissions inventory information on air pollutants in the GOM Region. BOEM collects the information through GOADS, as described most recently in BOEM NTL No. 2014–G01, and previous NTLs. The major pollutants for which BOEM has collected data in the GOADS include the following: CO, sulphur oxides (SOx), NOX, PM (including both PM10, and PM2.5), and volatile organic compounds (VOCs), including exempted compounds (40 CFR 51.100). BOEM also has collected information on GHGs, including CO2, methane (CH4), and N2O through the GOADS. The proposed rule would codify this current GOM practice, provide for the expansion of this activity to the North Slope Borough of the State of Alaska, and facilitate the gathering of information in other OCS areas to the extent necessary to augment the NEI or for another purpose such as to obtain relevant NEPA data. The proposed provision would require all lessees, operators, and holders of rights-of-use and easements (RUEs) to collect, maintain, and submit information on an ongoing basis regarding air pollutant emissions from all relevant emissions sources. BOEM would use this information to maintain a comprehensive OCS emissions inventory of air pollutants. The information would assist BOEM in meeting its requirements under OCSLA to ensure the offshore activities it authorizes do not significantly affect the air quality of a State. Also, the information submitted under this PO 00000 Frm 00031 Fmt 4701 Sfmt 4702 19747 provision would allow BOEM to determine OCS-wide emissions for leased areas and use that data to inform NEPA analysis and coordinate with the USEPA and coastal States to determine ambient air quality levels and mitigations of adverse impacts. The inventory will continue to augment BOEM’s NEPA review by providing an accurate inventory to determine ambient concentrations of air pollutants and by serving as a basis to compute emission trends and to perform necessary air quality impact assessments. Separately, the data provided by lessees, operators, and RUE holders are analyzed and supplemented by BOEM, and the results are provided to the submitters in order to assist them in complying with their reporting obligations to the USEPA. Under the proposed rule, BOEM would continue to make this information available to OCS lessees, lease operators, and RUE holders to assist with their mandatory reporting of certain GHGs to the USEPA. See 40 CFR 98.233. OCSLA requires DOI to make a decision on whether to approve an EP within 30 days and a DPP within 60 days. Consequently, the air quality review process for the plan is limited in its ability to provide extensive analysis of complex plans. Although not mentioned explicitly in OCSLA, BOEM’s regulations require a similar review timeframe for DOCDs. While there is an opportunity for public comment on plans, there is limited opportunity for public review of air pollution measures in EPs, DPPs, or DOCDs. BOEM requests comments on how more opportunity for public input could be provided, while observing legal constraints on plan review timeframes. J. Prevention of Significant Deterioration The AAIs established by the USEPA represent ambient concentrations of CPs in attainment areas that have been established to prevent the significant deterioration of air quality. Increases in ambient concentrations of CPs that exceed the AAIs present a risk of causing an attainment area to become a non-attainment area. BOEM proposes to evaluate increases in ambient air concentrations to ensure compliance with the AAIs. The preamble to the current regulation 64 stated that the maximum allowable increases (when added to the baseline concentration) ‘‘are ceilings which cannot be exceeded within an applicable area. To calculate the acceptable emission level, a lessee must 64 45 E:\FR\FM\05APP2.SGM Federal Register (FR) 15133 (Mar. 7, 1980). 05APP2 19748 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules combine the ambient air concentrations resulting from the projected emissions of total suspended particulates and SO2 from the proposed OCS facility with those emissions of TSP and SO2 from other onshore and offshore sources which contribute to the consumption of the maximum allowable increases.’’ There is, however, no provision in the current BOEM regulations that explicitly requires accounting for ‘‘other onshore and offshore sources which contribute to the consumption of the maximum allowable increases.’’ Accordingly, the proposed rule would contain an explicit requirement that facilities for which BACT is implemented consider other sources of emissions that contribute to consumption of the AAI when they compare the impacts of their controlled emissions against the AAIs. Through this notice, BOEM is soliciting comments on alternative ways for how it might effectively ensure that the increments are not ‘‘consumed’’ in the relevant attainment areas or what steps it might take to protect the increments in an operational context without creating an undue burden on lessees or operators. One alternative for determining the extent to which the increments have been ‘‘consumed’’ would be to separately evaluate the cumulative effects of offshore development in the context of the NEPA analysis conducted for the Five-Year Oil and Gas Leasing Program or in connection with the lease sales. Another alternative might be to conduct periodic cumulative impact assessments of the air quality in relevant attainment areas. Based on either the NEPA analysis or a separate cumulative impact assessment, BOEM might maintain a database of relevant AAIs that have previously been ‘‘consumed.’’ These data could be evaluated in the context of the plan review process, or separately in some other context. V. Section-by-Section Analysis of the Proposed Rule asabaliauskas on DSK3SPTVN1PROD with PROPOSALS The following are the changes proposed by this rulemaking in part 550: A. 30 CFR Part 550, Subpart A Section 550.101—Applicability The heading of § 550.101 would be revised from ‘‘Authority and Applicability’’ to read ‘‘Applicability.’’ This change would make the section title better reflect the current content of the section. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Section 550.102—What does this part do? The proposed rule would modify paragraph (a) of this section to make clarifying amendments. In addition, paragraph (b), which contains the table entitled ‘‘Where To Find Information For Conducting Operations,’’ would be updated as follows with the following additions: The acronym for application of permit to drill (APD); a reference to the subsection on Development and Production Plans (DPP) to include Development Operations Coordination Documents (DOCD); the acronym for geological and geophysical (G&G) permits; the acronym from oil spill financial responsibility, (OSFR); a subsection to cover Rights-of-Use and Easement; acronyms for Rights-of-Use and Easement (RUE) and pipeline Rights-of-Way (ROW); and a new subsection referencing the Air Quality proposed regulations in subpart C. Section 550.105—Revised Definitions Note on Definitions The definitions in § 550.105 are intended to apply to all of part 550. The definitions proposed to be added or revised in proposed § 550.302 are meant to apply only to § 550.205 of subpart B and all of subpart C. In many cases, the definitions as used in part 550 differ from the meaning of the same term found in other agencies’ regulations, in other contexts, or as used in common usage. Any word, phrase, or term that is not defined should be understood in the common and ordinary meaning of that word, phrase, or term. For example, the term nitrogen oxides is not defined, and it is not used in a manner that would require the term to be defined uniquely in this proposed rule, because BOEM uses it in its common and ordinary meaning. In contrast, the phrase ‘‘Best Available Control Technology,’’ and its corresponding acronym BACT, is used as defined in proposed § 550.302, and it would not have the same meaning as used in the USEPA regulation. Definitions related to air quality terms are currently located in three places in part 550: §§ 550.105, 550.200, and 550.302. Under the proposed rule, definitions of terms that are related solely to air quality would be located in § 550.302 as part of subpart C. Other definitions related to both air quality and other parts of the regulations are left in § 550.105. Subparts A and B contain some requirements related to air quality, and proposed sections within these subparts would use terms that would be defined in subpart C. Under this organizational framework, the proposed PO 00000 Frm 00032 Fmt 4701 Sfmt 4702 rule would move some of the definitions from one section to another and some terms would also be updated. The proposed rule would revise or add definitions of the following terms: Air Pollutant This definition would be revised to include the following: (1) Any criteria air pollutant for which the USEPA has established numerical criteria, referred to as the primary or secondary National Ambient Air Quality Standards (NAAQS), in 40 CFR part 50 and as may be amended pursuant to section 109 of the CAA; (2) any major precursor air pollutant identified by the USEPA that contributes to the formation of a criteria air pollutant through an atmospheric or photochemical reaction, including, but not limited to, VOCs, NH3, and those CPs that are also precursors for other CPs (such as SO2); and (3) any USEPAdefined GHG, as defined at 40 CFR 98.6 and as may be amended pursuant to section 111 of the CAA; and, (4) any USEPA-defined Hazardous Air Pollutant, as defined at 40 CFR 63.2 and as may be amended pursuant to section 112 of the CAA. The purpose of this change is to clarify that, while there are many types of air pollutants, the focus of BOEM’s regulatory efforts in this rulemaking is on the criteria and major precursor pollutants. Emissions Source The current regulations define the term ‘‘source’’ in section 550.302 as, ‘‘an emission point. Several sources may be included within a single facility.’’ The proposed rule would replace the term ‘‘source’’ with ‘‘emissions source’’ and locate the newly defined term in section 550.105. The proposed rule would define ‘‘emissions source’’ as ‘‘a device or substance that emits air pollutant(s) in connection with any authorized activity described in your plan.’’ The proposed definition would also clarify that several emissions sources may exist on a single facility, aircraft, vessel, or vehicle. The proposed rule would further make clear anything that: (1) Produces or results in the release of one or more air pollutant(s), including the flashing, flaring, or venting of natural gas; (2) involves burning any oil or well test fluids; or (3) generates fugitive emissions, is an emissions source. BOEM is proposing to use the term ‘‘emissions source’’ in place of the current term, ‘‘source,’’ since the term is used only in the air quality context (although referred to throughout part 550 of the regulations). The proposed definition of ‘‘emissions source’’ would be broader than the existing definition of ‘‘source.’’ It would also clarify that an E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules emissions source need not be part of a single facility. Examples of equipment that would fall under this proposed definition include, but not be limited to: Boilers/heaters/burners, diesel engines, drilling rigs, combustion flares, cold vents, glycol dehydrators, natural gas engines, natural gas turbines, pneumatic pumps, pressure/level controllers, amine units, tanks, dual fuel turbines, sources involved in mud degassing, storage tanks, well testing equipment, vessels (including support vessels, pipeline lay barges, pipeline bury barges, derrick barges), and any other equipment that could cause fugitive emissions, venting, losses from flashing, or loading losses. Federal Land Manager (FLM) The proposed rule would add this term to mean the Secretary of the Department with authority over any federal Class I area or sensitive Class II area (or the Secretary’s designee). This definition is adapted from USEPA regulations at 40 CFR part 51, subpart P, implementing the CAA provisions on protecting visibility in Class I areas. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federally-Recognized Indian Tribe For the purpose of this proposed rule, a Federally-recognized Indian tribe refers to a Federally-recognized Indian tribe that has either a Treatment as State (TAS) status recognized by the USEPA or an approved Tribal Implementation Plan (TIP). Flaring Under the current § 550.105, ‘‘flaring’’ is defined as ‘‘the burning of natural gas as it is released into the atmosphere.’’ The proposed rule would revise this definition to read, ‘‘. . . the burning of natural gas or other hydrocarbons and the release of the associated emissions into the atmosphere.’’ The proposed definition would also provide that, because lessees and operators can use flaring to reduce the emissions of hydrocarbon vapors, it could potentially also be considered as an air pollutant emission reduction measure. The proposed definition would further make clear flares can be a mechanism used to control emissions from storage tanks, loading operations, glycol dehydration units, vent collection systems, and amine units. In addition, the proposed definition would note flares usually operate continuously but some are used only for process upsets, which occur during the exploration or development process when large amounts of flammable gases are released suddenly and unexpectedly. Finally, the proposed definition would provide the term ‘‘flaring’’ is equivalent to combustion VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 flaring (i.e., burning of the gases), but it is distinct from cold venting, which involves the discharge of raw pollutants into the air without burning. BOEM is proposing to revise the definition of flaring and distinguish it from venting as a result of a response to Report 11–34 by the Government Accountability Office (GAO) in ‘‘FEDERAL OIL AND GAS LEASES: Opportunities Exist to Capture Vented and Flared Natural Gas, Which Would Increase Royalty Payments and Reduce Greenhouse Gases.’’ Minerals The proposed rule would revise the definition of the term ‘‘minerals’’ slightly to align with OCSLA section 2(q), 43 U.S.C. 1331(q). There would be no substantive changes to the definition for minerals, which continues to include oil, gas, sulphur, geopressuredgeothermal and associated resources, and all other minerals that are authorized to be produced from public lands. Mobile Support Craft (MSC) The proposed rule would add this term to the definitions section to mean ‘‘any offshore supply vessel (OSV) as defined by the USCG in accordance with 46 U.S.C. 2101, and any ship, tanker, tug or tow boat, pipeline barge, anchor handling vessel, facility installation vessel, refueling or ice management vessel, oil-spill response vessel, or any other offshore vessel, remotely operated vehicle (ROV), or any offshore vehicle used by, or in the support of, the offshore operations described in a plan.’’ Consistent with the approach currently used by BOEM, for the purpose of evaluating air emissions, an MSC is considered a facility while temporarily attached to the seabed or connected to another facility. Offshore Supply Vessel The term ‘‘offshore supply vessel’’ is defined in the USCG regulations. The term ‘‘support vessel’’ is used but not defined in the current BOEM regulations.65 BOEM’s regulations do specify, however, that the meaning of the term support vessel includes crew boats, supply boats, anchor handling vessels, tug boats, barges, ice management vessels, and other vessels, some of which do not qualify as offshore supply vessels under the USCG definition. Because of the potential confusion that could be caused by utilizing a term similar to that used by the USCG, BOEM proposes to revise its 65 See PO 00000 30 CFR 550.224 and 550.257. Frm 00033 Fmt 4701 Sfmt 4702 19749 existing regulations and replace the term ‘‘support vessel’’ with a new term, ‘‘Mobile support craft,’’ which would include offshore supply vessels as defined by the USCG, as well as any other vessel or vehicle used to support OCS exploration, development, production or transportation operations. Offshore Vehicle Current § 550.200 defines ‘‘offshore vehicle’’ as ‘‘a vehicle that is capable of being driven on ice.’’ The proposed definition would clarify that an offshore vehicle is a type of MSC that is capable of being driven on ice and would add the phrase ‘‘and which provides support services or personnel to your facility or facilities.’’ Right-of-Use and Easement (RUE) RUE is not currently defined in 30 CFR part 550. The proposed rule would define RUE to mean seabed use authorizations that BOEM may grant at an OCS site, other than an OCS lease, pursuant to sections §§ 550.160 through 550.166 of this part. State State is not currently defined in the regulations. The proposed rule would add this definition in order to clarify that the word ‘‘State’’ includes its submerged lands and extends to the federal/State boundary. Any reference to the word ‘‘State’’ in this proposed rule, unless otherwise specified, is intended to include the area offshore a State up to the federal/State boundary. Venting Venting is currently defined in 30 CFR 250.105. The proposed rule would modify that definition to read ‘‘the release of gas into the atmosphere, including though a stack without igniting it, whereby relief flows of natural gas or other hydrocarbons are directed to an unignited flare or which is otherwise discharged directly to the atmosphere. This includes gas that is released underwater and bubbles to the atmosphere.’’ Section 550.141—May I use or be required to use alternate documentation, procedures or equipment? The proposed rule changes the title from ‘‘May I ever use alternate procedures or equipment?’’ and would add new paragraph (d) to existing § 550.141, stating, ‘‘In order to protect public health, you may be required or allowed to temporarily suspend the use of equipment that emits air pollutants, or to implement operational control(s) on the use of such equipment by the Regional Supervisor, when an adjacent E:\FR\FM\05APP2.SGM 05APP2 19750 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS State or locality declares an air quality episode or emergency, provided that any such suspension or operational control(s) would not cause an immediate threat to safety or the environment.’’ The purpose of this provision is to ensure any BOEMauthorized equipment, which might contribute to air emissions episodes or air quality emergencies, could be turned off, or operated in a limited capacity, for the duration of such a declared emergency, as long as it can be done safely. Local air quality authorities in States adjacent to the OCS periodically declare air emissions episodes or air quality emergencies when the concentration of a pollutant is especially high. BSEE and its predecessors have historically either required or allowed the suspension of use and testing of standby equipment during emergency health episodes declared by local authorities adjacent to the Pacific OCS (NTL 2000 P–01). Such suspensions have, for example, allowed Pacific OCS operators the ability to curtail stationary source emissions according to the measures contained in Episode Avoidance Plans or Emergency Action Plans, which the operators typically prepare at the request of either the USEPA or the State. The proposed provision would apply more generally to any equipment authorized under part 550 and that emits air pollutants. It would also apply anywhere on the OCS where operations could contribute to an air quality emergency. A new provision has been added to accommodate situations in which published documents that are referred to in the regulations of this part have been updated by the original publisher. This provision would allow the use of the updated publications under certain circumstances, as specified in the proposed rule text. Section 550.160—When will BOEM grant me a right-of-use and easement, and what requirements must I meet? The proposed rule would redesignate current paragraphs (f), (g), (h), and (i) as paragraphs (g), (h), (i), and (j) and add a new paragraph (f). The new paragraph would specify that facilities constructed or maintained on RUEs must meet the air quality requirements of § 550.205 of subpart B of this part and that subpart C would also apply to that RUE application. The rule clarifies that any reference to a lessee or operator in those sections would apply equally to any applicant for a right-of-use and easement. The new provision of this section is intended to apply to those situations where an organization is proposing to VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 install a new facility on a RUE and that facility is not included in an exploration or development plan. In the event that an existing RUE was approved as part of an exploration or production plan, no new requirements would be imposed. Similarly, any application for a new RUE that is included within the scope of a proposed exploration or development plan would not be affected by the requirements of this paragraph. BOEM requests comments on the most appropriate method for establishing and reporting air quality requirements associated with the removal of any facility installed pursuant to a RUE in the context of the AQRP. Section 550.187—What region-wide offshore air emissions data must I provide? The proposed rule would add new § 550.187. The new section would require a lessee, an operator, or a holder of a RUE to collect, maintain, retain for a period of no less than 10 years, and submit to the appropriate regional office on an ongoing basis according to a schedule established by BOEM, information regarding all air pollutant emissions from all emissions sources associated with its operations. The primary means by which this requirement would be implemented is by requiring the lessees and operators to maintain records of the type and amount of fuel consumed (i.e., fuel logs) by all relevant sources. BOEM would use this information to maintain a comprehensive OCS emissions inventory of air pollutants. Currently, BOEM maintains this type of emissions inventory information on air pollutants in the GOM Region with the GOADS. The proposed rule would replace the name ‘‘GOADS’’ with the name ‘‘OCS emissions inventory’’ because the proposed rule anticipates the data collection would not be limited to the GOM in the future. The current BOEM practice is to require the submission of this information every three years, and BOEM intends to maintain this practice for the foreseeable future. The three-year timeframe is consistent with USEPA regulations regarding the timeframes for submitting this information. However, given that the USEPA may change its regulations and given that, in some cases, current USEPA regulations require more frequent reporting from some sources, the proposed regulations cross-reference USEPA regulations with respect to the timing of the information submittal. That way, the rule would propose to automatically reflect any changes made by the USEPA with PO 00000 Frm 00034 Fmt 4701 Sfmt 4702 respect to the NEI timing requirements. Accordingly, the proposed rule would specify that the reporting timeframes will be determined by the requirements of 40 CFR 51.30(a), as it may be amended. The proposed rule would require that the submitted information include air emissions or the activity data necessary to calculate the emissions of stationary emissions sources, including all facilities, and all non-stationary sources, including MSC(s) and any other nonstationary emissions source(s) of air pollutants above the OCS or above State submerged lands that operate in support of an OCS facility, as determined by the Regional Supervisor. GOM has historically obtained the MSC data from independent sources and intends to continue this process for the foreseeable future. BOEM would likely only change this practice if the data collection became impractical. Under the proposed rule, a lessee or operator may request that the owner of such non-stationary emissions source(s) provide the information to BOEM or a BOEM-designated agent, but the lessee or operator would still be responsible for submitting the required information if the owner does not submit it. Currently, the GOM Region prepares its emissions inventory by allowing lessees and operators to directly input data either on fuel use or on equipment usage and operating time. BOEM then uses this data to calculate the resulting emissions. This proposed rule would allow for the continuation of that practice in the GOM Region, and the expansion of that practice to other OCS regions. Accordingly, the proposed rule requires the submission of (1) facility and equipment usage, including hours of operation at each percent of capacity for each emissions source; and/or (2) fuel logs containing monthly and annual fuel consumption data showing the quantity, type, and sulphur content of fuel used for each emissions source. The proposed rule would require the information provided under this proposed section should be at a sufficient level of detail so as to facilitate BOEM’s compilation of a comprehensive OCS emissions inventory of air pollutants. BOEM solicits comments on various alternative methods for ensuring the accurate reporting of emissions and the appropriate methods that might be used to ensure the accuracy of the data and information it collects. Consistent with the approach taken by the USEPA in the development of the NEI, the proposed rule specifies that lessees and operators would be required to classify the emissions according to E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS the appropriate SCCs as defined by the USEPA in their Source Classification Codes listing, incorporated by reference in section 198(b)(1)(iv) of this chapter. The purpose of this requirement is to distinguish the various emissions processes including mobile source processes. The USEPA also estimates mobile source emissions of commercial marine vessels and without this distinction there would be a risk that either BOEM or the USEPA could double count the emissions that are reported. Finally, the proposed rule would allow the Regional Director to waive or allow a delay in compliance with the requirements of this section on a regionwide basis. The reason for this waiver provision is to allow regions to avoid duplicating the effort already undertaken by the USEPA in this regard, particularly in areas where BOEM does not have air quality jurisdiction and does not, therefore, have any unique or separate data or IC requirements. Under the proposed rule, a lessee, an operator, or a holder of a RUE would be required to submit the required information upon request or on an ongoing basis as determined by BOEM starting in 2017 or in the next reporting period if the rule is not effective by 2017 and continuing according to the timeframe established by the USEPA in its regulations governing the NEI to the appropriate regional OCS office. Leases and RUEs acquired after 2017 would be subject to the reporting requirement at the end of the next reporting period. The proposed rule would also require submission of this information more frequently if the lessee, operator, or holder of a RUE has an emissions source that generates facility emissions that have a PTE 66 such that it would qualify as a Type A source according to the USEPA’s regulations in table 1 of appendix A of subpart A.—Emission Thresholds by Pollutant for Treatment as Point Source of 40 CFR 51.50. These regulations contain thresholds set by the USEPA to determine which emissions sources within States require annual reporting to States for the NEI that the 66 The USEPA concept of PTE, which it defines at 40 CFR 51.301, is similar to the BOEM concept of facility emissions, in that both PTE and facility emissions refer to the maximum aggregate capacity of a stationary source to emit a pollutant under its physical and operational design. This concept includes all emissions sources attached to a facility but excludes the attributed emissions of nonstationary sources, such as MSCs. For further details on the concept and use of PTE in the USEPA context, see ‘‘Potential to Emit: A Guide for Small Business,’’ USEPA, Office of Air Quality Planning and Standards, Research Triangle Park, NC, EPA– 456/B–98–003, October 1998, available at: https:// www3.epa.gov/airtoxics/1998sbapptebroc.pdf. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 USEPA conducts for other sources every three years. As with the current GOADS in the GOM OCS region, the information obtained under this proposed provision is necessary to allow BOEM to determine more accurately air emissions from the activities it has authorized on the OCS and fulfill its statutory obligations under OCSLA section 5(a)(8). BOEM also uses that data to inform NEPA reviews and analysis and coordinate with the USEPA and coastal States. The inventory would provide data to augment BOEM’s NEPA review by providing an accurate basis from which to compute emission trends and to perform necessary air quality impact assessments. In addition, the emissions data derived from information provided under this program would continue to be made available from BOEM to OCS lessees, operators, and RUE holders to assist with their mandatory reporting of GHGs to the USEPA. BOEM would also continue to use the inventory to meet information requests from the general public. BOEM currently collects emissions data related to GHGs on a regular basis in the GOM OCS Region as part of the GOADS program. BOEM recognizes the impacts of GHG emissions on the air and water overlying the OCS, primarily associated with ocean acidification, and the States, in connection with climate change, and the importance and sensitivity of this issue. For this reason, BOEM is researching the implications of GHG emissions generated by OCS facilities and MSCs and evaluating various alternatives for potentially limiting these GHG emissions. Section 550.198—Documents Incorporated by Reference The proposed rule would incorporate by reference certain material into part 550 with the approval of the Director of the Federal Register under 5 U.S.C. 552(a) and 1 CFR part 51. The proposed rule would provide for the process BOEM may use to amend its regulations to incorporate different versions of these documents. For all material incorporated by reference, the applicable document would be the specific edition or specific edition and supplement or addendum cited in this section. Lessees and operators would be allowed to comply with a later edition of a specific document incorporated by reference, provided they show that complying with the later edition provides a degree of scientific or technical accuracy, environmental protection, or performance equal to or better than would be achieved by compliance with PO 00000 Frm 00035 Fmt 4701 Sfmt 4702 19751 the listed edition; and they obtain the prior written approval for alternative compliance from the authorized BOEM official. The proposed rule would explain that the effect of incorporation by reference of a document into the regulations in this part is that the incorporated document is a requirement. The proposed rule states that when a section in this part incorporates all of a document, the lessee or operator would be responsible for complying with the provisions of that entire document, except to the extent that the section which incorporates the document by reference provides otherwise. Further it states that when a section in this part incorporates part of a document, the lessee or operator would be responsible for complying with that part of the document as specified in that section. BOEM may issue the a future rule(s) amending the documents incorporated by reference effective without opportunity for public comment when BOEM determines the revisions to a document represent new industry standard technology and do not impose undue costs on the affected parties; and BOEM meets the requirements for making a rule immediately effective under 5 U.S.C. 553. The specific documents proposed to be incorporated by reference include: From the U.S. Environmental Protection Agency’s Office of Air and Radiation, 1200 Pennsylvania Ave. NW., MS6101A, Washington, DC 20460. (1) AP 42, Fifth Edition, Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Sources, January 1995, incorporated by reference at proposed § 550.205(b)(2). AP–42, Compilation of Air Pollutant Emission Factors, has been published since 1972 as the primary compilation of the USEPA’s emission factor information. It contains emission factors and process information for more than 200 air pollution source categories. A source category is a specific industry sector or group of similar emitting sources. The emission factors have been developed and compiled from source test data, material balance studies, and engineering estimates. The Fifth Edition of AP–42 was published in January 1995. Since then the USEPA has published supplements and updates to the fifteen chapters available in Volume I, Stationary Point and Area Sources. The latest emissions factors are available on their Web site at: https:// www3.epa.gov/ttnchie1/ap42/. (2) Motor Vehicle Emission Simulator (MOVES), User Guide, Assessment and Standards Division, Office of Transportation and Air Quality, EPA– E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19752 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules 420–B–14–055, July 2014, incorporated by reference at proposed § 550.205(b)(2)(iii)(B). The USEPA’s Motor Vehicle Emission Simulator (MOVES) is a state-of-the-science emission modeling system that estimates emissions for mobile sources at the national, county, and project level for criteria air pollutants, greenhouse gases, and air toxics. MOVES2014 is the latest version of MOVES. It incorporates significant improvements in calculating onroad and nonroad equipment emissions. MOVES201a does not significantly change the criteria pollutant emissions results of MOVES2014 and therefore is not considered a new model for SIP and transportation conformity purposes. The User Guide is available from the USEPA at: https://www3.epa.gov/otaq/models/ moves/documents/420b12001b.pdf. (3) User’s Guide for the Final NONROAD2005, EPA420–R–05–013, December 2005. This publication is applicable to the NONROAD2008 model, incorporated by reference at proposed § 550.205(b)(2)(iii)(B). The NONROAD model is intended for estimation of air pollution inventories by professional mobile source modelers, such as state air quality officials and consultants. The User Guide is available from the USEPA at: https:// www3.epa.gov/otaq/models/nonrdmdl/ nonrdmdl2005/420r05013.pdf. (4) FIRE (Factor Information Retrieval System) Version 5.0: Source Classification Codes and Emission Factor Listing for Criteria Air Pollutants, Office of Air Quality Planning and Standards, Office of Air and Radiation, EPA 454/R–95–012, Research Triangle Park, NC 27711, August 1995, incorporated by reference at § 550.187(c)(4). This document provides emissions factors and Source Classification Codes (SCCs) from the USEPA’s Factor Information Retrieval (FIRE) system, version 5.0, for use in the estimation, storage and retrieval of point source air pollutant emissions. Calculation of emission estimates is discussed as well as the SCC system of associating air pollution estimates with identifiable emitting process types or unit applications. This document is available from the USEPA at: https:// www3.epa.gov/ttn/chief/old/efdocs/ 454r95012.pdf. From the Federal Aviation Administration (FAA), Office of Environment and Energy (AEE–100), 800 Independence Avenue SW., Washington, DC 20591: (1) Aviation Environmental Design Tool (AEDT) User’s Guide, Version 2B, prepared for the FAA Office of Environment and Energy (AEE–100), VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Washington, DC prepared by U.S. Department of Transportation and Volpe National Transportation Systems Center, Cambridge, MA, July 2015 (as amended) incorporated by reference at § 550.205(b)(2)(iii)(D). AEDT is a software system that models aircraft performance in space and time to estimate fuel consumption, emissions, noise, and air quality consequences. AEDT is a comprehensive tool that provides information to FAA stakeholders on each of these specific environmental impacts. AEDT facilitates environmental review activities, such as those required under NEPA, by consolidating the modeling of these environmental impacts in a single tool. AEDT is designed to model individual studies ranging in scope from a single flight at an airport to scenarios at the regional, national, and global levels. AEDT leverages geographic information system (GIS) and relational database technology to achieve this scalability and offers rich opportunities for exploring and presenting results. Versions of AEDT are actively used by the U.S. government for domestic aviation system planning as well as domestic and international aviation environmental policy analysis. The User Guide is available from the FAA at: https://aedt.faa.gov/Documents/ UserGuide.pdf. (2) Aviation Environmental Design Tool (AEDT), Version 2B, AEDT Standard Input File (ASIF) Reference Guide, prepared for the FAA of Environment and Energy (AEE–100), Washington, DC prepared by U.S. Department of Transportation and Volpe National Transportation Systems Center, Cambridge, MA, May 2015 (as amended) incorporated by reference at § 550.205(b)(2)(iii)(D). This Reference Guide provides a description of the AEDT Standard Input File (ASIF) file format. It is intended for analysts and programmers who wish to create or modify an ASIF to import data into an AEDT study. The Reference Guide is available from the FAA at: https:// aedt.faa.gov/Documents/ ASIFReferenceGuide.pdf. From the International Maritime Organization, 4 Albert Embankment, London SE1 7SR, United Kingdom, or https://www.imo.org, or 44–(0)20–7735– 7611: (1) Revised MARPOL Annex VI, Regulations for the Prevention of Air Pollution from Ships, and NOX Technical Code [NTC] 2008, 2009 edition, incorporated by reference at proposed section 550.205(b)(2)(v). This publication presents the revised MARPOL Annex VI, Regulations for the prevention of air pollution from ships, PO 00000 Frm 00036 Fmt 4701 Sfmt 4702 and the updated NOX Technical Code 2008, including amendments adopted by resolutions MEPC.202(62), MEPC.203(62) and MEPC.217(63), as well as Guidelines and other information relevant to improved energy efficiency for ships and the prevention of air pollution. MARPOL Annex VI includes requirements for control of emissions from ships (chapter 3) and new regulations on energy efficiency for ships (chapter 4) that entered into force on 1 January 2013. These make mandatory the Energy Efficiency Design Index (EEDI) for new ships and the Ship Energy Efficiency Management Plan (SEEMP) for all ships. The publication is available from the International Maritime Organization (IMO) at: https:// www.imo.org/en/Publications/ Documents/Newsletters%20and %20Mailers/Mailers/IB664E.pdf. This, and the other IMO publications, may also be ordered directly from the IMO at: https://www.imo.org/en/ Publications/Documents/Catalogue%20 and%20Book%20Code%20Lists/ English/Catalogue.pdf. (2) Revised MARPOL Annex VI, Regulations for the Prevention of Pollution from Ships (‘‘2008 Annex VI’’), incorporated by reference at proposed § 550.205(b)(2)(v). This adds various amendments to the annex of the protocol of 1997 to amend the International Convention for the Prevention of Pollution from Ships. It is available from a USEPA Web site at: https://www3.epa.gov/nonroad/marine/ ci/mepc58-23-annexes13-14.pdf. (3) NOX Technical Code 2008, incorporated by reference at proposed § 550.205(b)(2)(v). This document amends the technical code on the control of emissions of nitrogen oxides from marine diesel engines. It is available from the IMO Web site at: https://www.imo.org/en/OurWork/ Environment/PollutionPrevention/ AirPollution/Documents/Air%20 pollution/Resolution%20 MEPC.177(58)%20NOx%20 Technical%20Code%202008.pdf. B. 30 CFR Part 550, Subpart B The following are the changes proposed by this rulemaking in part 550: Section 550.200—Definitions Offshore Vehicle The proposed rule would move the definition of this term into § 550.105 because it is used more often outside the air quality context and is referred to throughout the regulations in part 550. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Section 550.205—What air emissions information must be submitted with my plan (EP, DPP, DOCD, or application for a RUE, pipeline ROW, or lease term pipeline)? In the current regulations, plan requirements related to air quality are widely dispersed. Air quality requirements are discussed throughout part 550, particularly in §§ 550.207, 550.212, 550.218, 550.224, 550.225, 550.227, 550.242, 550.249, 550.257, 550.258 and 550.261. In order to provide a consistent, comprehensive listing of all of the data requirements related to air quality, these existing air quality regulations would be consolidated in one new section, ‘‘§ 550.205 What air emissions information must be submitted with my plan (EP, DPP, DOCD, or an application for a RUE, pipeline ROW, or lease term pipeline)?’’ Most references to air quality requirements in the other sections of part 550 would be deleted and replaced with a cross-reference to the single new § 550.205. In addition, the proposed rule would specify that this section would apply to RUE, pipeline ROW, and lease term pipeline applications. Paragraph 550.205(a)—Emissions Sources The proposed rule would make clear that all lessees or operators must list and describe every emissions source on or associated with any facility or facilities and MSC(s) described in a plan. In contrast to the current regulations, the proposed rule describes in detail what should be considered an emissions source and what should or should not be included in that category. The proposed rule adds specificity to the requirements to ensure plans and RUE, pipeline ROW, and lease term pipeline applications are prepared consistently and evaluated according to a standard set of criteria. This would include each emissions source used during the construction, installation (including well protection structure installation), and operation of any exploration, testing, drilling (including well test flaring), development, or production equipment or facility or facilities (including every platform or manmade island included in their plan). The proposed rule would specify lessees or operators must account for the air pollutant emissions sources associated with all drilling operations, including workovers and recompletions, sidetracking, and pipeline construction, and reported emissions sources must include those associated with any oil or gas produced on a lease that is used VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 during the course of lease operations (i.e., any beneficial use of produced oil or gas). The proposed rule would require the list of emissions sources to cover the duration of the proposed plan’s activities. The proposed rule would require lessees or operators to specify the equipment type and number, manufacturer, make and model, location, purpose (i.e., the intended function of the equipment and how it would be used in connection with the proposed activities covered by the plan) and physical characteristics of each emissions source. It would also require reporting of the type and sulphur content of fuel stored and/or used to power each emissions source and the frequency and duration of the proposed use. The proposed rule would contain additional provisions for engines on facilities and MSCs. For all engines on each facility, including non-road engines, marine propulsion engines (in the case of MODUs when attached to the seabed), or marine auxiliary engines (i.e., a nonroad or highway engine on a vessel that is used to power a crane, a drill, or an auxiliary power unit, but it is not installed on a marine vessel, as defined at 40 CFR 1042.901), the lessee or operator would be required to identify and provide the engine manufacturer, engine type, fuel type, engine identification, and maximum rated capacity of the engine, to be expressed in kilowatts (kW), if available. If a lessee or operator has not yet determined what specific engine would be used, it would be allowed to provide analogous data for a comparable engine with the greatest maximum rated capacity for the type of engine that it will use. For this purpose, BOEM would consider a comparable engine to be one having similar operational and emissions characteristics and similar operational and physical limitations. Under the proposal, if the engine for which the lessee or operator provides documentation has physical design and operational limitations and these limitations are the basis of its emissions calculations, then the lessee or operator must provide documentation of such limitations. For engines on MSCs, including marine propulsion and marine auxiliary engines, the proposed rule would require lessees or operators provide information regarding the engine displacement in liters/cylinder, and maximum speed in revolutions per minute (rpm). If the specific rpm information is not available, the proposed rule would require the lessee or operator to indicate whether the rpm PO 00000 Frm 00037 Fmt 4701 Sfmt 4702 19753 would be less than 130 rpm, equal to or greater than 130 rpm but less than 2,000 rpm, or equal to or greater than 2,000 rpm, based on best available information. For offshore vehicles and MSCs, the proposed section would provide that when a lessee or operator does not know which specific engines will be used or the information about them cannot be verified, it may estimate maximum potential emissions based on the maximum potential emissions of the type of MSC typically used in the planned operations. Finally, for any emissions source that does not fall into one of these categories, the proposed rule would require lessees or operators to provide all information needed to calculate and verify the associated emissions, such as volumes vented, volumes flared, size of tank, number of components, etc. Paragraph 550.205(b)—Emissions Factors The purpose of this section is to provide information regarding how a lessee or operator would determine the level of air emissions for each emissions source described in its plan. The proposed rule would provide a considerable amount of detail regarding what emissions factors should be used. Emissions factors are the values that allow lessees or operators to calculate how much of a pollutant will be emitted based on the operation of the source. The proposed rule would retain the current requirement that, for each emissions source, for every criteria and major precursor air pollutant, the lessee or operator must identify the most appropriate emissions factor(s) for calculating its projected emissions. The proposed rule would specify the acceptable methods to be used for determining the appropriate emissions factors. In general, a lessee or operator would be allowed to use actual emissions amounts derived from emission testing done for a specific emissions source in lieu of one of the approaches to estimate emission factors set out below. When determining the emissions factors through testing, the lessee or operator must consider test points and fuel. In general, unless the unique circumstances of the proposed plan make it clearly impractical to do so, test points should be devised based on actual operations as opposed to using the test points and engine loads contained in one of the various marine or non-road duty cycles. It cannot be assumed that emissions per hour or emissions per kW or per hp hour from large main engines on drill ships and platforms are highest during full load or E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19754 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules near-full load operation. Large main engines on drill ships and platforms typically operate at less than half full power, and emissions factors for some pollutants during this operation may be significantly higher than at full load or near-full load. Specifically, actual maximum emissions per hour or emissions per kW or horse-power hour may not be properly estimated by assuming 90% load, since emissions factors for different pollutants can have different variation with load. Under the proposed rule, the emissions factor and emission per hour or emissions per kW or per horse-power hour for the operation that is actually expected should be determined, and the emissions under 90% load should be used only if emissions at this load are the highest and thus conservative. The proposed rule would further specify that the lessee or operator must ensure that the fuel used in the testing to generate the emission factors reflect the type of fuel that will be used by the engine in actual operation. The sulphur content is especially important with respect to measuring PM and SOX emissions. The proposed rule would specify that in the event that the lessee or operator were to elect not to measure the actual emissions for any given emissions source, it would need to select an emissions factor from the list of sources provided in the proposed rule. These are described below, in the order of preference. First, the proposed rule would provide that the lessee or operator use the emissions factor(s) that are vendorguaranteed or provided by the manufacturer of the specific emissions source, if available. If the lessee or operator were to use vendor-guaranteed or manufacturer data, it would need to demonstrate (1) that the fuel used by the manufacturer to generate the emission factors reflects the type of fuel that will be used by the engine in actual operation and (2) that the actual engine has not been modified outside the configuration used to generate the emission factors; thus, the emission factors used in the plan must represent the actual pattern of use for that equipment in operations. The proposed rule would specify that where a manufacturer has not provided an emissions factor for the emissions source the lessee or operator proposes to use, the lessee or operator may use a manufacturer’s emissions factor for a similar source only if the lessee or operator could demonstrate to the satisfaction of the Regional Supervisor that the emissions generated by the lessee or operator’s emissions source are VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 the same as or lower than that for which a manufacturer’s emissions factor is available. Second, the proposed rule would state that emissions factors generated from source tests required by USEPA Outer Continental Shelf permits would be allowed as BOEM emission estimates for a specific rig since these emissions factors are based on prior emissions tests. These emissions tests are required across the range of actual load operations for engines on Mobile Offshore Drilling Units (MODU). The proposed rule would further specify that if emissions factors were not generated through testing for a particular engine, emissions factors generated from a recent and similar permitted engine may be used.67 Data from a rig from the same manufacturer, having an engine of the same model and year would generally be allowed, unless the Regional Supervisor has a reason to believe that such data may not be accurate or reliable. Third, if emission factors, based on models or an emission model guidance document developed by the USEPA or FAA is available and appropriate to the emissions source, the lessee or operator may use the relevant emission factors from that model or guidance document. The proposed rule would provide a list of emission models that may be used to obtain emission factors for certain types of emissions sources. In particular, two referenced documents from the USEPA provide in-use emission factors for a variety of engines including ‘‘Category 3’’ main propulsion engines on vessels and engines used in equipment on vessels, covering both engines certified to USEPA emission standards and engines certified by other nations and international organizations. Fourth, the lessee or operator would use emission factors from published studies conducted by a reputable source, such as the South Coast Air Quality Management District, California Air Resources Board, a university, or research agency, to the extent they may yield reliable emission factors or formula to calculate emissions factors for certain types of engines and equipment other than for the large main engines on drilling ships and drill platforms and for locomotive-sized engines powering cranes. These studies may be helpful to generate emission factors for marine coating operations, flares, emissions from drilling muds, etc. If an emission study is used, the study must cover representative engines, fuels, and duty cycles. 67 I.e., the same make, model and year engine would be required. PO 00000 Frm 00038 Fmt 4701 Sfmt 4702 Fifth, in certain situations, the MARPOL Annex VI engine emission standards may be used as proxies for emission factors. This option would be available only for an engine installed on a non-U.S. flagged vessel that is not part of an engine family that is covered by a USEPA certificate of conformity but that is MARPOL certified. In this case, the lessee or operator must indicate the vessel flag as well as engine size used to determine the standards to use as the proxy emission factor for that engine. If this approach is used, the plan would also be required to account for any differences in fuel sulphur limits.68 If all fuel used by the subject drilling ships and offshore platforms is purchased in the U.S., the CAA fuel requirements would apply. BOEM seeks comment on: (1) Whether this fifth alternative would be appropriate or is needed, particularly given that the emission factors used in USEPA’s marine and nonroad emission models apply regardless of flag (i.e., emissions from similar engines in similar use regardless of whether the engine is on a US or a foreign-flag vessel); (2) how such an approach would be applied to engines that use Heavy Fuel Oil, since the NOX Technical Code (NTC) allows engines to be certified on diesel fuel (which can have relatively high sulfur content); and, (3) what approach could be taken to estimate pollutants other than NOX (since there are no MARPOL standards for the majority of criteria and precursor pollutants) and, if using one of the other approaches is preferred, whether the NOX emission factors from those other approaches should be used and this fifth alternative be not adopted. Sixth, under the proposed rule, if none of the methods provided in the first five options above are applicable, for a natural gas-powered engine of any 68 Under Annex VI, the NO engine type X certification is separate and not related to the fuel sulphur limits. The technical code for certifying Annex VI Regulation 13 engines requires ‘‘suitable’’ testing fuel be used and that the characteristics of the testing fuel be noted for the certification. Vessels operating in North American/Caribbean Emissions Control Area (ECA) are all required to use 0.1% sulfur fuel, regardless of the flag of the vessel and regardless of where the fuel was purchased. Vessels may also achieve compliance within the ECA by receiving an Annex VI Regulation 3 trial permit or Regulation 4 equivalency determination, in lieu of using the 0.1% sulphur fuel. If the MSC operations associated with the facility are all within the ECA and the Annex VI Reg13 engine was tested using 0.1% sulfur fuel, there would be no differences in fuel sulphur limits to account for. However, it is recognized that the ECA is smaller than the OCS area impacted by this regulation so vessels may not be using 0.1% sulfur fuel, and that the Annex Regulation 13 engine may have been certified using a fuel different from the fuel used during operations. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules rated capacity, or for a non-road dieselpowered engine with a maximum rated capacity less than 900 kW, or for a nonengine emissions source, the lessee or operator could use the appropriate emissions factor from the USEPA AP 42, Fifth Edition, Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Emissions sources, or any update thereto, as incorporated by reference at § 550.198(b)(1)(i). Seventh, if none of the above options are applicable,69 the lessee or operator would be required to conduct stack testing on the emissions source to determine the appropriate emissions factor. The data from stack testing could be used only for the engine for which the stack testing was conducted. If a lessee or operator elects to apply an emissions factor based on a standard, as allowed under the 5th and 6th alternatives, it must take appropriate account of the deterioration in performance based on the age of the equipment and the potential variation of the actual emissions from the standard to account for the maximum potential emissions that the emissions source may emit. Given that equipment tends to operate less efficiently over time, the lessee or operator should make an appropriate upward adjustment in the emissions estimates for older equipment (e.g., to reflect emission deterioration over time). BOEM solicits comments and suggestions on how this might most appropriately be conducted and the extent to which there are appropriate, documented, methodologies for making these kinds of adjustments. The proposed rule would also require that any time a lessee or operator revises a plan, including as a part of its resubmissions every ten years, it must consider the age of the equipment, adjust for any change in operating efficiency, and provide the associated emissions factors in its revised or resubmitted plan, as applicable. Also, under the proposed rule the Regional Supervisor may require a lessee or operator to use a different emissions factor for any emissions source or air pollutant if the Regional Supervisor has reason to believe the selected emissions factor is inaccurate to a material degree or new information on emissions factors becomes available. The proposed rule would also provide the Regional Supervisor may require stack testing or another form of validation to verify the accuracy of an emissions factor. 69 This option is not required as the first alternative because stack testing is generally very expensive and limits the flexibility of operators in preparing their plan(s) (because stack testing is engine-specific). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 19755 Various U.S. manufacturers of nonroad and marine diesel engines produce both domestic and export-only versions of each piece of equipment. The domestic version is manufactured to comply with USEPA emissions requirements whereas the export-only version may or may not comply with USEPA requirements. Domestic versions may, in some cases, be exported. Manufacturers in other countries also produce, or may in the future produce, both engines that are certified by the USEPA as legal for sale in the U.S. and engines that are not. The USEPA provides emissions factors for such equipment that is certified to be legal for use in the U.S., and these emission factors apply to an originally-configured U.S.-certified engine regardless of its marketing path. It does not test or evaluate the emissions of U.S.manufactured equipment intended only for export or foreign-manufactured equipment not intended for sale in the U.S. For this reason, under the proposed rule, if a lessee or operator proposes to utilize an engine or equipment that is manufactured in the U.S. or any other country, but which is not certified by the USEPA for use in the U.S., the lessee or operator may not use a USEPA emissions factor intended to apply to the domestic version of such engine or equipment of the same vintage. Under the proposed rule, if a lessee or operator proposes to utilize an engine or equipment on a U.S.-flagged vessel that is not USEPA-certified for use in the U.S., then that lessee or operator must test the actual emissions of the proposed engine or equipment and submit data on its actual emissions. If the lessee or operator claims to use a USEPA certified engine or equipment, it must submit documentation of that engine or equipment’s certification. Under the proposed rule, if a lessee or operator’s projected emissions include emissions for a U.S. flagged vessel, then it must submit documentation of the USEPA-issued Certificate of Conformity for each mobile source engine.70 For MARPOL-compliant foreign-flag equipment for which no other emissions factor data are available, MARPOL emissions standards may be used to determine proxy emission factors where such emissions standards are available (see 5th option, above).71 However, if this source is used, the plan must account for any differences in the fuel Paragraph 550.205(c)—Facility Emissions This paragraph is intended to provide a consistent set of criteria to determine what should be included in each plan with respect to facilities and their corresponding emissions. This paragraph would require facility emissions to be reported for each criteria and major precursor air pollutant in three separate ways. First, paragraph (c)(1) would require the lessee or operator to calculate and report the projected annual emissions for each facility in its plan, itemized by all of the emissions of each emissions source on or physically connected to each facility. Such calculations should be done for each year that the plan is proposed to engage in operating activities, for a period of ten years. Emissions reported under this subparagraph would include those associated with any emissions source involved in the construction, installation, operation, or decommissioning of the facility, based on the maximum rated capacity of each emission source associated with the facility and using the methods and procedures specified under paragraphs (a) and (b) of this section. Second, paragraph (c)(2), would require the lessee or operator to calculate and report the maximum 12-month rolling sum 72 of emissions from each emissions source on or connected to each facility and the maximum 12-month rolling sum of the emissions from each facility. The purpose of this latter requirement is to 70 The USEPA requires that all U.S.-flagged vessels must have engines certified by the USEPA. 71 MARPOL emission standards and certification requirements for Category 3 propulsion engines are similar to those of the USEPA, and USEPA emission factors appropriately matched to the vintage and type of engine may be used for such engines. 72 The plan must include the emissions for the 12 consecutive month period in which the emissions are projected to be the greatest, regardless of the calendar year in which those months occur. All references to 12-month rolling sum are intended to refer to 12 consecutive month intervals without any overlap. PO 00000 Frm 00039 Fmt 4701 Sfmt 4702 sulphur limits applicable to the fuel being used for operations and the sulphur limit of the fuel used for emission testing. All fuel used by the subject drilling ships and offshore platforms would be required to either be purchased in the U.S. or comply with applicable CAA fuel emissions requirements, unless the lessee or operator could demonstrate that it has properly accounted for any differences in emissions that may result from the use of non-U.S. fuel. If a lessee or operator proposes to use any engine or equipment that is neither USEPAcertified nor MARPOL-compliant, then it may not use an emissions factor intended to apply to a MARPOL compliant engine or equipment. In that case, the lessee or operator would be generally required to provide actual emissions test results for the engine. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19756 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules identify the peak emissions that would be expected to occur during any 12month period within the duration of the plan. Third, in paragraph (c)(3), the proposed rule would require lessees or operators calculate the maximum projected peak hourly emissions from each emissions source on or physically connected to each facility and the maximum projected peak hourly emissions from each facility that would result from the construction, installation, operation, or decommissioning of the facility. The proposed rule would specify the lessee or operator must calculate its projected emissions from each emission source, based on the maximum rated capacity of each engine it proposes to use, or the capacity that generates the highest rate of emissions. Emissions information would be required for emissions sources individually and for the entire facility or facilities. BOEM expects it would implement this proposed requirement by continuing its current practice whereby lessees and operators provide information on their emissions in a table that they submit with their plan. BOEM intends this requirement to be broad, and accordingly, the proposed rule also defines ‘‘emissions sources’’ and ‘‘facilities’’ broadly. (See discussion of definitions of those terms at §§ 550.105 and 550.302). The requirement to report facility emissions exists in the current regulations, but the proposed rule would refine the requirement. The result of these broad definitions in the context of this proposed section would be that all sources of emissions connected to a facility should be accounted for in a plan. Examples of emissions sources on platforms that a lessee or operator would be required to report under this proposed section include, but are not limited to, boilers/heaters/burners, diesel engines, drilling rigs attached to the seabed, combustion flares, cold vents, fugitives, glycol dehydrators, losses from flashing, natural gas engines, natural gas turbines, pneumatic pumps, pressure/level controllers, amine units, loading losses, tanks, dual fuel turbines, and sources involved in mud degassing or storage tanks. Examples of sources that would also be accounted for under this proposed section that normally are not on a platform include, but are not limited to, drilling rigs, and any other equipment that is temporarily or permanently connected to any planned facility. This would include any support vessel (crew, supply, tugs), pipeline lay barges, pipeline bury barges, derrick barges (installation of structure), and well VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 testing equipment, while connected or moored to the facility. The USEPA concept of PTE, which it defines at 40 CFR 51.301, is similar to the BOEM concept of facility emissions, in that both PTE and facility emissions refer to the maximum aggregate capacity of a stationary source to emit a pollutant under its physical and operational design. In both cases, this concept includes all emissions sources attached to a facility but excludes the attributed emissions of unattached non-stationary sources.73 For further details on the concept and use of PTE in the USEPA context, see ‘‘Potential to Emit: A Guide for Small Business,’’ USEPA, Office of Air Quality Planning and Standards, Research Triangle Park, NC, EPA–456/ B–98–003, October 1998, available at: https://www3.epa.gov/airtoxics/ 1998sbapptebroc.pdf. BOEM is considering whether to use the term PTE instead of facility emissions, and BOEM invites comment on this question. Paragraph 550.205(d)—Attributed Emissions (i.e., Non-Facility Emissions) Proposed § 550.205(d) specifies how emissions from MSCs described in a plan would be attributed to a facility described in that plan. The proposed section provides the procedures by which operators would account for emissions from these MSCs while they are supporting the operations in the plan. Under the proposed rule, lessees and operators would be required to calculate both the total emissions that every MSC in its plan generates and then to calculate the portion of that total that should be attributed to their facility. First, for each facility described in a plan, a lessee or operator would be required to identify the MSCs that would be used to support that facility. The lessee or operator, to the extent practicable, would also be required to identify the other facilities each MSC would support. Second, for each such MSC, the lessee or operator would calculate its emissions per trip, from when the MSC leaves its home port until it returns (i.e., support emissions per trip), irrespective of what other facilities the MSC may also service. The lessee or operator would be required to base such calculations on the maximum rated capacity or the capacity that generates the highest rate of emissions for each emissions source on the MSC. Having done this, the lessee or operator would 73 However, as defined by BOEM, a nonstationary source, such as a vessel, vehicle or aircraft could also have a potential to emit. PO 00000 Frm 00040 Fmt 4701 Sfmt 4702 multiply this result by the number of trips the MSC would take in support of the facility during the 12 consecutivemonth rolling maximum period over which the corresponding facility emissions would be measured. In addition, each lessee or operator would also have to determine and report the maximum projected peak hourly emission for each MSC. If an MSC does not support any other facilities, the proposed rule would require the lessee or operator to attribute all of these emissions to the facility the MSC supports. However, if an MSC supports multiple facilities, the proposed rule would then provide three alternative methods for calculating the portion of total MSC emissions that lessees and operators would be required to attribute to their facility. First, a lessee or operator could, to the extent practicable, calculate and report the difference between the total support emissions and the emissions it can document should be reasonably allocated to another facility. This option would be available to lessees or operators who know detailed information about the routes of the MSCs in their plans and what other facilities each MSC would support. Second, if the first method is impracticable but the lessee or operator knows the number of facilities supported by any given MSC (but not their locations or the routes of the MSC), the operator could divide the total support emissions by the lowest number of the facilities the operator reasonably determines the MSC will serve on a typical trip, including the facilities described in its plan. If neither of these two methods is practicable, the rule would allow operators to calculate and report the greater of either (1) the emissions that would be generated by the MSC traveling round trip between its port or home base and the facility, or (2) the emissions from the MSC operating within 25 statute miles of the facility. Finally, the proposed rule would allow lessees or operators the ability to elect to attribute the total support emissions of any vessel or vehicle to their facility if they decide not to allocate the emissions among facilities. The proposed rule includes the options described above because a lessee or operator may not know, at the time of plan submittal, which facilities an MSC will support. The intent is to provide these alternatives for allocating support vessel emissions in situations where it would otherwise be impracticable to do so. The options in the proposed rule are intended to account for the variety of practices that E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS could occur on the OCS and the ability to know the particular operation of an MSC at the time of plan submittal. With respect to proposed § 550.205(d)(7), although that requirement is only one of the assumptions that are to be used in calculating the MSC emissions, the provision is intended to clarify it would not be appropriate to calculate the emissions only for one source, in the event an MSC had multiple sources of relevant emissions. The rule is intended to clarify the maximum rated capacity requirement applies to each source on every MSC, in any situation where an MSC has multiple emissions sources. Further, the proposed rule would provide that if BOEM questions the lessee or operator’s determination of the attributed emissions, the Regional Supervisor may require additional documentation to support their findings and may direct them to make changes, as appropriate. Finally, just as BOEM is considering using the term PTE in place of the term facility emissions, BOEM is also considering using USEPA’s term secondary emissions (as defined in 40 CFR 51.301) in place of attributed emissions. BOEM welcomes comment on this question. Paragraph 550.205(e)—Projected Emissions (i.e., Combined Facility and Attributed Emissions) This paragraph is intended to provide a detailed, consistent set of criteria to determine what should be included in each plan with respect to projected emissions of facilities and MSCs. Proposed § 550.205(e) would require a lessee or operator to calculate the maximum 12 month rolling sum of projected emissions of each criteria and major precursor air pollutant for each of its facilities. This would represent the sum of the facility emissions for the 12month rolling maximum period reported under (c)(2) of this section and attributed emissions reported under (d)(6) of this section for the same period. Pursuant to the criteria set forth in proposed § 550.303(d), the lessee or operator would also be required to determine whether the projected air emissions from each facility would need to be consolidated with those of other facilities. If any of a lessee’s or operator’s proposed facilities would be located in such a manner (as defined in § 505.303) as to potentially constitute proximate activities with a pre-existing facility, or a facility that was previously approved but not yet constructed, the proposed rule would require any such facility to be identified in the plan. If the lessee or VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 operator would be required to consolidate emissions from multiple facilities, then it would need to provide projected emissions information for each facility as well as the complex total emissions for all of consolidated activities. In addition, the proposed rule would also require every lessee or operator to calculate and report the projected annual emissions for its facilities for each year in which it intends to operate, as well as the maximum peak hourly emissions for each facility and the corresponding attributed emissions. Paragraph 550.205(f)—Emission Reduction Measures (ERM) The purpose of this paragraph is to describe in general terms the information that must be included in a plan regarding the types and purpose of various emission reduction measures that are proposed in a plan and what reductions the lessee or operator expects to achieve from these proposed measures. Under the proposed rule, a lessee or operator may elect to propose ERM in its plan to ensure that its projected emissions are under the EETs described in proposed § 550.303. Whether an operator elects to propose ERM or whether the proposed rule would require it, this section would require that such proposed measures be reported in the plan. This element of the proposed rule is consistent with current GOM Region practice. It would specify that the lessee or operator must provide a description of all proposed ERM, including the affected emissions source(s); the emissions reduction control technologies, procedures, and/or operational limits; the emission control efficiencies; the projected quantity of reductions to be achieved; and, any monitoring or monitoring system the submitter proposes to use to measure or evaluate the associated emissions. The rule would further clarify the lessee or operator must be able to demonstrate that all of the ERM described in the plan meet the applicable substantive requirements in proposed § 550.309. BOEM expects lessees or operators are likely to consider operational controls to reduce emissions for many sources, for example limiting the hours of operation, reducing engine power, etc., in order to bring their projected emissions within the EETs. This proposed section would require the application of such operational controls to be documented in the plan, which would require review by the Regional Supervisor, and approval only when the ERMs are demonstrated to maintain and not compromise the safety of operations. PO 00000 Frm 00041 Fmt 4701 Sfmt 4702 19757 Other sections of the proposed rule, such as proposed §§ 550.309 and 550.311, would subject each proposed emission reduction measure to monitoring, reporting, and verification. Geological sequestration of pollutants under the seabed is another potential emission reduction measure that has not yet been considered. BOEM would welcome feedback on the extent to which stakeholders consider this to be a potentially viable and effective control mechanism, either in conjunction with or as an alternative to other measures. Paragraph 550.205(g)—Modeling Information This paragraph is intended to provide a detailed, consistent set of information and criteria to determine what should be included in each plan submitted to BOEM with respect to the proposed modeling of air emissions associated with a plan’s projected operations. If a lessee or operator conducts modeling in support of its plan, then the proposed rule would require the lessee or operator to provide: A table(s) of the appropriate and relevant maximum projected air pollutant concentrations over any area(s) of any State(s) and Class I area(s) including the most affected attainment area(s) and the most affected non-attainment area(s), as applicable; the maximum projected concentrations resulting from the projected emissions for each of the facilities, by criteria air pollutant and major precursor air pollutant, for the corresponding averaging time(s) (e.g., 1-hour, 3-hour, 8hour, 24-hour, annual, etc.) specified in the tables in 40 CFR 51.165(b)(2), 40 CFR 52.21(c), and 40 CFR part 50; a list of the inputs, assumptions and default values used for modeling, including the source and justification for meteorological information; the name and version of the model(s) used; a modeling report, including the modeling results (unless already provided and the projected emissions are the same or lower); and, for each MSC, the distance from the facility or facilities in the plan to the relevant home port or base. All of this information is necessary so BOEM can properly evaluate and validate the results of the modeling. Under the proposed rule, if a lessee or operator would be required to model projected emissions, and the lessee or operator has previously submitted a modeling report and/or modeling results to the Regional Supervisor, then the lessee or operator may provide a reference to such report and/or results, rather than resubmit a modeling report and/or modeling results, provided the projected emissions are the same or E:\FR\FM\05APP2.SGM 05APP2 19758 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules lower than in the previously submitted report(s) or results. Paragraph 550.205(h)—Requirements Applicable to Specific Air Pollutants 550.205(h)(1)—Nitrogen and Sulphur Oxides (NOX and SOX) Because the intent of the proposed rule is to evaluate the maximum potential effect that could occur with respect to the implementation of any given plan, the proposed rule would clarify a lessee or operator must utilize data for NOX and SOX whenever possible or reasonable estimates thereof. Projected emissions of NOX would need to include emissions of nitrogen oxide and NO2, as well as any other oxides of nitrogen for which data are available. Similarly, any projected emissions of SOX would need to be reported, including but not limited to the emissions of SO2. Only in the event that data on the broader emissions of NOX or SOX are not available, would the proposed rule specify a lessee or operator could utilize data on the sum of nitrogen oxide and NO2 emissions as a substitute for NOX and data on SO2 emissions as a substitute for SOX. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 550.205(h)(2)—PM10 and PM2.5 Because the USEPA has replaced ‘‘total suspended particulates’’ with two separate kinds of pollutants, a lessee or operator would be required to provide data and information on both PM10 and PM2.5, whenever such information is available for any given emissions source, and to evaluate each separately under every applicable standard in all cases where it is possible to do so. This should not present an issue, since the split in the PM classification has existed for quite a few years. Only in the rare event that available data for PM are not separately reported for both PM10 and PM2.5 for any given emissions source, would the proposed rule require lessees and operators to perform their analysis of PM2.5 emissions utilizing PM10 data for the emissions threshold analysis and for modeling purposes. However, the proposed rule specifies a lessee or operator must separately identify all PM2.5 and PM10 emissions in its plan and a plan that fails to contain separate emission exemption threshold and modeling data for each pollutant will not be considered complete. Because there are separate SILs, AAIs and NAAQS for PM10 and PM2.5, and also because the PM2.5 evaluations require an evaluation of the ambient impacts of both direct and secondary PM2.5, a plan may not be submitted that includes and addresses only PM10 emissions. If the separate data are not VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 available, the lessee or operator must utilize the data for PM10 for its analysis of PM2.5, (assuming the PM2.5 is as high as the PM10). Finally, the proposed rule clarifies that all reporting of PM2.5 must include the sum of filterable and condensable PM, if such information is available, in order to be complete. 550.205(h)(3)—Hydrogen Sulfide (H2S) To properly estimate the potential emissions of SOX under this proposed paragraph, all emissions of SOX that result from the flaring of H2S would need to be included in the projected emissions of SOX reported and analyzed as part of each plan. Under the proposed rule, if projected emissions of H2S will potentially exceed the USEPA’s Significant Emissions Rate for H2S, as defined in 40 CFR 52.21(b)(23)(i), the lessee or operator must report the nature and extent of these emissions and their likely impact as part of its plan. The proposed rule would specify that reporting of H2S would be required to follow the USEPA’s Oil and Natural Gas Sector New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants Reviews. These are described more specifically in ‘‘Oil and Natural Gas Sector: New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants Reviews,’’ 77 FR 49489, RIN 2060– AP76, October 2012. Aside from the proposed § 550.205, BOEM is also proposing to modify §§ 550.215 and 550.245 regarding H2S such that if a lessee or operator proposes to flare gasses containing a potentially significant amount of H2S, it must separately identify this activity in the plan and separately identify the resulting emissions of SOX. 550.205(h)(4)—Methane (CH4) This rule implements BOEM’s statutory authority under OCSLA section 5(a)(8) to regulate OCS air pollutant emissions from oil and gas operations in order to prevent adverse, localized air quality effects to adjacent States; since there are no significant localized air quality effects on the States associated with the emissions of methane from OCS facilities, BOEM is not proposing to regulate methane emissions in this context. Under the proposed rule, the analysis or reporting of methane emissions would not be required unless specifically directed to the contrary. Consistent with current BOEM policy, any reference in these proposed regulations to major precursor air pollutants would exclude methane, PO 00000 Frm 00042 Fmt 4701 Sfmt 4702 because the USEPA does not include methane in the definition of VOCs and does not require a methane analysis of ground level ozone formation for offshore facilities; both because methane has not historically been considered a significant precursor air pollutant with respect to distances and transport times relevant to BOEM regulation of offshore activities; and because the USEPA has not elected to formally classify methane as a precursor pollutant for O3. BOEM solicits comments on this proposed exclusion and on how BOEM should address the effects of methane emissions on secondary O3 formation and under what circumstances it would be appropriate, in the event it decides to do so. 550.205(h)(5)—Ozone (O3) Over the past 35 years, extensive scientific evidence has increasingly demonstrated the importance of controlling O3, and the significant potential harm this pollutant can cause. Additionally, as a result of improvements to single source photochemical modeling capabilities, it is now possible to evaluate much more accurately how the emissions of O3 precursors may contribute to O3 formation and how this may affect the air quality of the States. Reflecting the changes in the NAAQS and the improvement in modeling capabilities that have occurred over the past 35 years, BOEM is now proposing to evaluate O3 directly for compliance with the NAAQS. The proposed rule would not immediately require analysis or reporting of O3. Rather, once the new emissions exemption studies have been completed, new EETs would likely be established to address O3 impacts to the State. Proposed paragraph 550.304(b) details the circumstances when O3 modeling would be required. Comments may be submitted as to how this would best be accomplished and at what point in time the implementation of these new standards would be most appropriate. 550.205(h)(6)—Lead (Pb) and Ammonia (NH3) Ammonia (NH3) has been identified as a potentially significant precursor air pollutant for PM2.5. The proposed rule would require reporting of NH3 emissions, for any given source, if that information is available. Such a determination would be based on whether there are published manufacturer specifications of emissions factors for NH3, whether such information could be obtained from the USEPA, or whether it could be obtained or could be derived from another E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules recognized source, such as utilizing a mass balance approach. Lead (Pb) is a CP for which NAAQS have been established. For this reason, consistent with the OCSLA mandate, like NH3, reporting of Pb emissions would be required to the extent relevant information is available or could be derived from another recognized source, such as utilizing a mass balance approach. Because of BOEM’s obligation under OCSLA to ensure compliance with the NAAQS, BOEM is proposing that all emissions of NAAQS pollutants should normally be reported. If the lessee or operator intends to use a source known to emit a potentially significant amount of Pb or NH3, then it must obtain a reasonable estimate of the associated Pb or NH3 emissions. For that reason, the proposed rule specifies that zero emissions for Pb and NH3 may be assumed only in the situation where relevant data are not available and neither the lessee or operator nor BOEM have a reason to anticipate that the emissions could be potentially significant. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Paragraph 550.205(i)—Distance Calculations To determine the appropriate EET for each facility in a plan, the proposed rule would retain the requirement that the lessee or operator provide the distance in statute miles, from the shoreline, until such time as the new thresholds are established in 2020. Because the proposed rule intends to retain the current exemption methodology for a period of time and then replace that methodology,74 two distance measures would be proposed in this rule. As is currently required by BOEM regulations, the first would be the distance from shore, as measured in a straight line from the site of each facility to the closer of the mean high water mark of a State or, on the Pacific coast, the mean higher high water mark, or the nearest Class I area of any State. The second would be the distance from a State’s seaward boundary. For each facility described in the plan, the lessee or operator would be required to calculate and provide the distance in 74 As discussed in the context of proposed § 550.303(c), the proposed rule would continue to retain the shoreline as the point at which emissions are evaluated until such time as the new scientific studies have been completed and new exemption thresholds have been defined. At that time, BOEM would evaluate all emissions at the SSB and any facility that generates emissions in excess of a SIL at the SSB would have to apply ERM. For this reason, the distance calculation used by the exemption formulas would be the distance to shore, in the first instance, and the distance would be the distance to the SSB, in the second instance. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 statute miles, as measured in a straight line from the site of the facility to the closest point at which the OCS borders any State, at the seaward boundary. Paragraph 550.205(j)—Documentation Unlike the current regulations, which do not specify any documentation or data retention requirements, the proposed rule outlines the data and recordkeeping requirements BOEM proposes to require to facilitate BOEM’s evaluation and review of each plan and the corresponding operational activities that result from each plan. This information would be used to verify compliance with BOEM regulatory requirements and to ensure that compliance with such requirements continues on an ongoing basis. The proposed rule would require lessees or operators to collect, create, and maintain records or any data or information establishing, substantiating, and verifying the basis for all information, data, and resources used to calculate their projected emissions under proposed section 550.205. The proposed rule would require documentation of the emissions factors used and retention of any appropriate certifications, citations, methods, and procedures used to obtain or develop emission factors. The proposed rule would require collection and maintenance of all documentation pertaining to the modeling analysis, if applicable, including all references and copies of any referenced materials, as well as any data or information related to any ERM lessees or operators propose or implement. Under the proposed rule, all such information would need to be provided to BOEM, though the Regional Supervisor would be able to waive this requirement for good cause or if BOEM is able to obtain the necessary information from an independent source. Paragraph 550.205(k)—Compliance With Subpart C The proposed rule would require lessees and operators to provide a description of how they will comply with proposed section 550.303 when the projected emissions generated by the proposed plan activities exceed the respective EETs. The proposed rule would require lessees and operators to make this determination using the formulas in proposed paragraph 550.303(c). If the lessee or operator would be subject to the requirement to monitor and report its actual emissions in accordance with section 550.311, then the description must address how it proposes to monitor its emissions. PO 00000 Frm 00043 Fmt 4701 Sfmt 4702 19759 Paragraph 550.205(l)—Reporting The proposed rule would require lessees and operators to submit data and information in a format and using the forms specified by BOEM. They would be required to submit information in an electronically-readable spreadsheet, such as a Microsoft Excel file on a compact disc, unless otherwise directed by the Regional Supervisor. The purpose of this requirement is to facilitate the evaluation of data by automated processes and systems. Under the current arrangement, data are submitted to BOEM in approved Excel spreadsheets. Although the proposed rule does not specify a specific format for electronic forms, it is likely the current spreadsheets will continue to be used for the foreseeable future.75 The USEPA is currently working on an E-Enterprise solution for emissions data collection, whereby facilities (or companies) would report emissions data through a central place for distribution to USEPA, the States, and others. Since BOEM is proposing direct facility reporting as well, BOEM may elect to partner on this E-Enterprise solution for supporting BOEM’s needs alongside those of the USEPA. This approach may be more efficient both for the regulated entities as well as for USEPA and BOEM to use and share the data. BOEM welcomes comment on this alternative and whether there may be any impediments or complications should BOEM wish to move in this direction. If lessees and operators elect to transmit the information to BOEM electronically, such as by email, then they would be required to use a delivery medium or transmission method authorized by BOEM. The purpose of this requirement is to ensure any data or information provided to BOEM is provided in a secure and safe manner and such information is not submitted in a way (e.g., email) that could be intercepted or manipulated by third parties. DOI has established standards and requirements for the secure transmission of data on an approved technology platform and BOEM intends to adhere to DOI requirements (although it may do so using a BOEM-specific transmission mechanism, such as the Technical Information Management System Web-based application, abbreviated TIMS-Web). 75 Currently, BOEM utilizes OMB-approved forms BOEM–0134 and BOEM–0135 for this purpose. The forms are being revised in connection with this rulemaking. BOEM also solicits comments on the proposed new forms, in terms of their usefulness, readability, complexity and completeness. E:\FR\FM\05APP2.SGM 05APP2 19760 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Paragraph 550.205(m)—Additional Information Section 550.211—What must the EP include? landward of the SSB, not only onshore, as is currently the case. Proposed § 550.205(m) would set out the circumstances under which a lessee or operator would be required to include information about emissions from aircraft and from those onshore support facilities for which the lessee or operator does not have an USEPA or State agency air quality permit (i.e., ‘‘a non-permitted onshore facility’’). The proposed requirement would be triggered when the modeling of air emissions indicates that a plan’s proposed emissions would cause an increase in the ambient air quality at any receptor location that exceeds 95% of a SIL. If an operator or lessee would be required to report emissions from any aircraft or non-permitted onshore support facilities and they support multiple OCS facilities, the lessee or operator would be required to allocate their emissions in an appropriate manner similar to that described for MSCs. Under such circumstances, a lessee or operator would be required to include such emissions in the information required under proposed section 550.205 and proposed subpart C. The proposed rule would also permit the Regional Supervisor to require such additional data or information related to these sources as is necessary to demonstrate the plan’s compliance with subpart C of this part, and/or applicable federal laws related to the protection of air quality within BOEM jurisdiction. Paragraph 550.211(c)—Drilling Unit Paragraph 550.215(e)—Hydrogen Sulfide As explained above in the discussion of § 550.205, the proposed rule would amend this section and section 245 by adding a paragraph in each to specify flaring of any gasses containing a potentially significant amount of H2S would be required to be separately identified in the plan, along with the resulting emissions of SOX. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Paragraph 550.205(n)—Requirements for Plans To Be Deemed Submitted In order for a plan to be deemed submitted, all of the required air quality data and information would be required to be submitted to BOEM in accordance with the requirements of this part. BOEM would not initiate its review of the air quality component of any plan until all of the necessary information and documentation is complete. To facilitate this, the proposed rule would specify that a plan would not be deemed submitted in accordance with the requirements of § 550.231 or 550.266 of this part until: (1) All of the requirements of this section have been completed; (2) The lessee, or operator, has completed the AAI analysis as specified in § 550.307(b) of this part, if it is required; and (3) The lessee, or operator, has completed any other analysis required by subpart C of this part. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 The current regulation at § 550.211(c) includes a provision that requires a description of the ‘‘fuels, oil and lubricants that will be stored on the facility.’’ The regulations state the word ‘‘facility’’ is defined in § 550.105. However, the section to which the current regulations refer no longer exists in BOEM’s regulations. That provision was originally in the regulations administered by BOEM’s predecessor before it was divided into BOEM and BSEE, and was subsequently moved into the BSEE regulations at § 250.105. The original definition of the term ‘‘facility,’’ to which the references in §§ 550.211 and 550.241 refer, was: ‘‘a vessel, a structure, or an artificial island used for drilling, well completion, wellworkover, or production operations.’’ Because this definition of facility no longer exists, BOEM is proposing to add this definition back into §§ 550.211 and 550.241 where its use remains applicable, with minor modifications for clarity. No substantive change to § 550.211 or 550.241 is being proposed. For the purpose of this section, the term facility would mean any installation, structure, vessel, vehicle, equipment or device that is temporarily or permanently attached to the seabed of the OCS, including an artificial island used for drilling, well completion, wellworkover, or other operations. Section 550.212—What information must accompany the EP? This section describes the information that must be included in an EP. The change to the proposed rule for this section would update the crossreference in § 550.212(f) from §§ 550.218 to 550.205, since the air quality requirements of § 550.218 are proposed to be relocated there. Section 550.215—What hydrogen sulfide (H2S) information must accompany the plan? Paragraph 550.215(d)(2)—Hydrogen Sulfide Under the proposed rule, if the H2S emissions are projected to affect any location within a State in a concentration greater than 10 parts per million, the modeling analysis would need to be consistent with the USEPA risk management plan methodologies outlined in 40 CFR part 68. The only change made with this revision would be that the concentration of 10 parts per million would be measured at any point within the State including any point PO 00000 Frm 00044 Fmt 4701 Sfmt 4702 Section 550.218—What air emissions reporting must accompany the plan?— Removed and Reserved Sections 550.218 and 550.249 in the current regulations set forth the air quality reporting requirements of subpart B for exploration plans and development plans, respectively. All of the substantive requirements from these two sections would be consolidated into the new proposed section 550.205 and modified as discussed above. Accordingly, §§ 550.218 and 550.249 would become reserved. Section 550.224—What information on support vessels, offshore vehicles, and aircraft must accompany the plan? Paragraph 550.224(a)—General Current regulations require plans to include a description of the vessels, offshore vehicles, and aircraft lessees and operators would use to support their exploration activities (§ 550.224(a)) or their development and production activities (§ 550.257(a)). The proposed rule would reword paragraph (a) of the proposed sections for clarity and to incorporate the term MSC, proposed for definition in this rule, but the meaning and intent of these paragraphs would not be changed. The proposed rule would retain the current requirement to include in the description an estimate of the storage capacity of the fuel tanks and the frequency of visits to the facilities in connection with any proposed activities. Paragraph 550.224(b)—Air Emissions Paragraph (b) of both the current paragraphs (§§ 550.224(b) and 550.257(b)) requires plans to include information regarding air emissions from vessels, vehicles, and aircraft described in the plan. The proposed rule would replace this paragraph with a cross-reference to proposed § 550.205. That proposed section, described above, would provide details about what emissions information for MSCs must be included in a plan. However, that proposed section would not generally require information on aircraft E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules emissions. As explained above, aircraft emissions contribute only a small fraction of emissions, and aircraft emissions information is especially burdensome to collect. Accordingly, BOEM believes it is not prudent to require lessees and operators report aircraft emissions in most cases. The proposed rule would normally only require general information about aircraft used in a plan under proposed paragraph (a), since it is necessary for the Regional Supervisor to verify whether emissions from these sources may contribute to exceeding an emission exemption threshold or an AAQBS. In some limited circumstances, where the emissions of aircraft may be determinative of whether the plan does or does not cause a significant impact to any State or tribe, the reporting of aircraft emissions may be required, as described in proposed § 550.205(m). asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Section 550.225—What information on the onshore support facilities must accompany the plan? Paragraph 550.225(b)—Air Emissions The current paragraph (b) of both §§ 550.225 and 550.258 requires lessees and operators to provide in their plans a description of the source, composition, frequency, and duration of the air emissions likely to be generated by the relevant onshore support facilities. The proposed rule would not substantively change this requirement, but the proposed rule would revise it for clarity. The proposed rule would delete the parenthetical text in the current paragraphs—‘‘attributable to your proposed exploration activities’’ and ‘‘attributable to your proposed development and production activities’’—in order to avoid confusion with the use of the term ‘‘attributed emissions’’ in proposed § 550.205. The proposed rule would limit the current requirement for onshore emissions sources in order to reduce unnecessary reporting and focus reporting requirements on areas with the greatest potential impact. BOEM currently requires reporting of onshore support facility emissions as may be necessary for the Regional Supervisor to determine whether emissions from these sources may contribute to exceeding an EET or an AAQSB, as described in the preamble section on proposed § 550.205(m). This requirement in the current regulations is based on the premise that there may be some circumstances where the amount of air pollution generated by onshore support facilities, taken in conjunction with the offshore emissions associated with OCS operations, could have a potentially VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 significant impact to the air quality of the States. However, BOEM believes that the requirement can be made more appropriately tailored to limit unnecessary reporting, while still incorporating select onshore emissions information in appropriate circumstances. As described more fully in the preamble discussion of proposed § 550.205(m), the proposed rule would collect information on onshore support emissions if two specific criteria are both met: (1) If a plan which is already required to conduct modeling results in incremental increases in concentration of a pollutant that are greater than 95 percent of the value of a SIL (this is the same criteria that applies to the inclusion of aircraft); and (2) if the relevant onshore support facilities are not already permitted by the USEPA or a relevant State authority. The goal of this proposed provision is to incorporate significant data that may contribute to OCS permitted activity affecting the air quality of the states but to avoid collecting unnecessary information. BOEM solicits comments on this proposal, both with respect to whether gathering data on onshore support facilities is necessary and/or appropriate and what criteria should be used to determine the circumstances under which data about onshore support facility emissions should be collected. BOEM uses the information that would be required in this paragraph for the analysis of cumulative impacts it performs under NEPA. The proposed rule would also provide that the information regarding onshore support facilities would only be required by BOEM if it is not available from another agency. BOEM can obtain some of the information for proposed and existing onshore support facilities for use in its NEPA or other environmental analyses through the USEPA or other air quality agencies. BOEM solicits comments on what types of onshore facilities should be identified and reported with respect to their air emissions and how best to evaluate their emissions in the context of the AQRP. Section 550.241—What must the DPP or DOCD include? Paragraph 550.241(c)—Drilling Unit and Paragraph 550.241(d)—Production Facilities The change proposed here is analogous to the change proposed at § 550.211. The current regulations at § 550.241(c) and (d) include provisions that require a description of drilling units and production facilities in a DPP PO 00000 Frm 00045 Fmt 4701 Sfmt 4702 19761 or DOCD. This description includes ‘‘fuels, oil and lubricants that will be stored on the facility’’ or ‘‘the estimated maximum quantity of fuels and oil that will be stored on the facility,’’ respectively. The current regulations state the word ‘‘facility’’ is defined in § 550.105(3). However, the section to which the current regulation refers no longer exists in BOEM’s regulations. That provision was originally in BOEM’s predecessor’s regulations before it was divided into BOEM and BSEE and was subsequently moved into the BSEE regulations at § 250.105. The original definition of the term facility, to which the reference in § 550.241 refers, was: ‘‘a vessel, a structure, or an artificial island used for drilling, well completion, wellworkover, or production operations.’’ Because this definition of facility no longer exists, BOEM is proposing to add this definition back into § 550.211(c) and in § 550.241, with minor modifications for clarity. No substantive change to § 550.241 is being proposed. For the purpose of this section, the term facility would mean any installation, structure, vessel, vehicle, equipment or device that is temporarily or permanently attached to the seabed of the OCS, including an artificial island used for drilling, well completion, wellworkover, or other operations. Section 550.242—What information must accompany the DPP or DOCD? This section describes the information that would be required to be included in a DPP or DOCD. The change to the proposed rule for this section would update the cross-reference in § 550.212(g) from §§ 550.249 to 550.205, since the air quality requirements of § 550.249 are proposed to be relocated there. Section 550.245—What hydrogen sulfide (H2S) information must accompany the plan? Paragraph 550.245(d)(3)—Hydrogen Sulfide Emissions See the discussion for § 550.215(d)(2). Paragraph 550.245(e)—Hydrogen Sulfide See the discussion for § 550.215(e). Section 550.249—What air emissions reporting must accompany the plan? See the discussion for § 550.218. Section 550.257—What information on support vessels, offshore vehicles, and aircraft must accompany the plan? Paragraph 550.257(a)—General and Paragraph 550.257(b)—Air Emissions See the discussion for § 550.224. E:\FR\FM\05APP2.SGM 05APP2 19762 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Section 550.258—What information on the onshore support facilities must accompany the plan? Paragraph 550.258(b)—Air Emissions See the discussion for § 550.225. Section 550.280—How must I conduct activities under the approved EP, DPP, DOCD, RUE, pipeline ROW, or lease term pipeline application? The proposed rule would modify the title of this proposed section from ‘‘How must I conduct activities under the approved EP, DPP, or DOCD?’’ to ‘‘How must I conduct activities under the approved EP, DPP, DOCD or RUE, pipeline ROW, or lease term pipeline application?’’ In addition, the proposed rule would modify paragraph (a) of the current regulations, which specifies that a lessee or operator must conduct all of its activities in accordance with an approved EP, DPP, or DOCD and any approval conditions. This provision would be modified to clarify that a lessee or operator may not install or use any facility, equipment, vessel, vehicle, or other emissions source not described in the approved EP, DPP, DOCD, or application for RUE, pipeline ROW, or lease term pipeline and that a lessee or operator may not install or use a substitute for any emissions source described in an EP, DPP, DOCD, or application for a RUE, pipeline ROW, or lease term pipeline without prior BOEM approval. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Section 550.284—How will BOEM require revisions to the approved EP, DPP, DOCD, or application for a RUE? Paragraph 550.284(a)—Periodic Review The proposed rule would modify the title of the section from ‘‘How will BOEM require revisions to the approved EP, DPP, or DOCD’’ to ‘‘How will BOEM require revisions to the approved EP, DPP, DOCD or application for a RUE?’’ Paragraph (a) of the current section specifies the Regional Supervisor will periodically review the activities conducted under an approved EP, DPP, or DOCD and the frequency and extent of this review is based upon changes to ‘‘available information and onshore or offshore conditions.’’ The proposal would modify this paragraph to clarify that the frequency and extent of the review may be based on any changes in applicable law or regulation as well. Existing § 550.284(b) allows the Regional Supervisor to require modifications to plans based on such a review. The proposed rule would not change this paragraph. As discussed below, proposed § 550.310(c) would complement the proposed change to § 550.284(a) by making explicit that the VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Regional Supervisor may require a lessee or operator to submit a revised plan when an applicable AAQSB changes. BOEM does not anticipate that it would invoke this provision except in extraordinary circumstances and, even under those extraordinary circumstances, it would rarely, if ever, require the resubmission of a plan under this provision more frequently than every ten years. other CPs and precursor pollutants would also not be defined in the regulations and because BOEM applies the common meaning of this term, as used by the USEPA and other federal agencies. C. 30 CFR Part 550, Subpart C Subpart C is being replaced in its entirety with a new subpart C dedicated to air pollution prevention and control. Air Quality Control Region (AQCR) AQCR would be newly defined to mean ‘‘an interstate area or major intrastate area, which the USEPA deems appropriate for assessing the regional attainment and maintenance of the primary or secondary national ambient air quality standards described in 42 U.S.C. 7409, as identified under 40 CFR part 81, subparts A and B, Designation of Air Quality Control Regions.’’ Section 550.301—Under what circumstances does this subpart apply to operations in my plan? This section would specify that the proposed subpart applies to those areas of the OCS where DOI has authority to regulate air emissions pursuant to section 5(a)(8) of the OCSLA, 43 U.S.C. 1334(a)(8), as amended, and jurisdiction pursuant to section 328(b) of the CAA, 42 U.S.C. 7627(b), as amended. This section explains the proposed subpart would apply to all plans related to facilities on the relevant areas of the OCS, regardless of the type of plan (EP, DPP, or DOCD or application for a RUE, pipeline ROW, or lease term pipeline). The section would also state that the subpart covers existing facilities in the relevant areas. Section 550.302—Acronyms and Definitions Concerning Air Quality Paragraph (a) of the proposed rule would update the acronym list used to identify those acronyms that are relevant to the proposed rule. In addition, the proposed rule would clarify that the definitions proposed to be added or revised in proposed § 550.302 are meant to apply only to § 550.205 of subpart B and all of subpart C. Deleted Definitions The following three terms in the current definitions § 550.302 would be removed from the list of definitions in proposed § 550.302: ‘‘source,’’ ‘‘temporary facility,’’ and ‘‘volatile organic compound.’’ The proposed rule would move the term ‘‘source,’’ renamed ‘‘emissions source,’’ from § 550.302 into proposed § 550.105, because it would be used in portions of part 550 outside of subpart C. The term ‘‘temporary facility’’ would be replaced with a new term ‘‘short-term facility’’ (although the meaning and purpose of the term would be similar). The proposed rule would not define the term ‘‘volatile organic compound,’’ since PO 00000 Frm 00046 Fmt 4701 Sfmt 4702 New or Revised Definitions Paragraph (b) would list the definitions used in subpart C, as follows. Ambient Air Increments (AAIs) AAIs would be newly defined to mean ‘‘the national standards for Ambient Air Increments set out in the table in 40 CFR 52.21(c), as amended.’’ These are national ambient air benchmarks that represent the maximum increase in pollutant concentrations allowed for an onshore area of a State designated by the USEPA as a Class I, Class II, or Class III area. Depending on the level of the AAIs, various ERM may be required by BOEM under subpart C. In the current BOEM regulations, the AAIs are referred to as the MACIs, as set out in the table in the current regulation at 30 CFR 550.302. Ambient Air Standards and Benchmarks (AAQSB) AAQSB would be newly defined to refer collectively to all of the standards and benchmarks referenced in this proposed subpart. These would include the SILs, in 40 CFR 51.165(b)(2) (pursuant to 42 U.S.C. 7401 et seq.); the AAIs, as set out in the table in 40 CFR 52.21(c) (pursuant to 42 U.S.C. 7473); and the primary and secondary NAAQS defined in 40 CFR part 50 (pursuant to 42 U.S.C. 7409). Attainment Area The current regulations define this term in § 550.302, and the proposed rule would revise the definition. The proposed rule would modify the definition of attainment area to mean ‘‘for any given criteria air pollutant, a geographic area, which is not designated by the USEPA as being a designated non-attainment area, as codified at 40 CFR part 81 subpart C.’’ Thus, any area not specifically listed by the USEPA as a designated non-attainment area would E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS be classified as an attainment area under this proposed rule, including areas that the USEPA’s regulations refer to as attainment, maintenance, unclassifiable, or unclassifiable/attainment as well as areas that have not yet been designated because the two-year period to complete such designations after revision of a NAAQS has not yet passed. The proposed definition would also clarify that the same area may constitute an attainment area for one criteria air pollutant and a designated nonattainment area for another criteria air pollutant (see definition of nonattainment area). Second, because there may be multiple NAAQS averaging times for each CP, any given area may be attainment for one pollutant for one averaging time and non-attainment for the same pollutant over a different averaging time. Third, this definition would clarify that the term attainment area, as used by BOEM, is intended to include onshore unclassifiable areas (i.e., areas that cannot be classified as attainment or designated nonattainment areas) or any other areas that the USEPA has not explicitly classified as designated non-attainment. Attributed Emissions This new term would be defined to mean ‘‘for any given criteria or precursor air pollutant the emissions from MSCs, operating above the OCS or State submerged lands, that are attributed to a facility pursuant to the methodology set forth in § 550.205(d), for the period over which the corresponding facility emissions are measured.’’ BOEM intends for this proposed definition to encompass the emissions that are generated from nonstationary sources that support a planrelated facility and must be evaluated in connection with the air quality component of the plan review. The specific requirements for calculating attributed emissions are set out in proposed § 550.205(d). Given that BOEM is proposing to provide various alternative methods to calculate attributed emissions, it may be possible these alternatives could yield slightly different overall results and the option chosen may not result in the highest potential calculation of attributed emissions that might be derived. Providing for these alternative methods reflects the reality that all relevant or necessary data may not be available to a lessee or operator at the time its plan is prepared and submitted to BOEM. Regardless of the ultimate method used to allocate MSC emissions and derive attributed emissions, however, no lessee or operator will be allowed to emit air pollutants in an VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 amount that exceeds what was approved in its plan and a lessee or operator generating emissions in excess of its plan approval could be subject to sanctions, including potential shut-in for a violation. In addition, under this proposed rule, there are specific monitoring and record-keeping provisions that would be added to ensure ongoing compliance with the proposed regulations. For this reason, BOEM anticipates that lessees or operators will be conservative in emissions allocations. Background Concentration This new term would be defined to mean ‘‘the ambient air concentration of any given criteria air pollutant that arises both from local natural processes and from the transport into the airshed of natural or anthropogenic pollutants originating locally or from another location, either as measured from an USEPA-approved air monitoring system or as determined on some other appropriate scientifically justified basis, as approved by BOEM.’’ The background concentration of a pollutant represents the concentration of any given pollutant that is present prior to the establishment of operations related to a proposed facility. Evaluating compliance with the NAAQS requires the consideration of two factors, (1) the background concentration of any given pollutant at the point of measurement, and (2) the contribution to the concentration that would be generated as a result of the facility being proposed. The incremental amount of the pollutant that is contributed by the operations associated with a plan is added to the background concentration of that pollutant in order to determine the amount of pollution that would exist as a result of the implementation of the proposed plan. The sum of the background concentration for any given pollutant and the incremental amount of the pollutant resulting from the implementation of the proposed plan is referred to as the design concentration of that pollutant. That design concentration represents the value that is compared to the NAAQS in order to determine whether or not the plan, if implemented as proposed, would cause an exceedance. Baseline Concentration The term baseline concentration would be defined as the ambient background concentration of any given air pollutant which exists or existed at the time of the first application for a USEPA PSD permit in an area subject to sec. 169 of the CAA, based on air quality PO 00000 Frm 00047 Fmt 4701 Sfmt 4702 19763 data available to the USEPA or a State air pollution control agency and on the monitoring data provided in the permit application. The proposed definition would also state that the baseline concentration is distinguished from the background concentration in that the background concentration changes continually over time to reflect the current ambient air concentration for any given air pollutant, whereas the baseline concentration remains fixed until such time as a new AAI is established for an attainment area. The difference between the current background concentration and the baseline concentration represents the change in actual concentration of a given pollutant in a relevant area caused by natural and/or anthropogenic (i.e., other stationary and non-stationary) sources that began operations after the date the baseline concentration was established. Best Available Control Technology (BACT) This term would be revised from the definition that exists in the current regulation. The proposed rule would define BACT to mean ‘‘a physical or mechanical system or device that reduces emissions of air pollutants subject to regulation to the maximum extent practicable, taking into account (1) the amount of emissions reductions necessary to meet specific regulatory provisions; (2) energy, environmental, and economic impacts; and (3) costs.’’ This proposed definition and usage of the term would differ from that of the USEPA, because the USEPA’s use of BACT refers to changes made in connection with the USEPA’s permit process under the CAA, and BOEM does not issue air quality permits, nor does it make determinations of BACT pursuant to the CAA. Rather, BOEM requires (and is proposing to continue requiring) BACT in its review and approval of plans for which modeling has demonstrated that projected emissions may cause or contribute to an exceedance of an applicable AAQSB or a violation of the NAAQS. In addition, BOEM and the USEPA differ in their requirements for BACT, primarily due to the difference in their respective regulatory frameworks. BOEM reviews the BACT alternatives as part of its AQRP, under both the current regulation and the proposed rule prospectively, determining in advance of the facility installation what form of BACT is appropriate. The USEPA also evaluates BACT prospectively, but the CAA also specifies, among other requirements, that BACT cannot be less stringent than any applicable standard E:\FR\FM\05APP2.SGM 05APP2 19764 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules of performance under the New Source Performance Standards (NSPS) (42 U.S.C. 7479(3)). Therefore, although BOEM looks to USEPA practices when evaluating control technologies, due to the unique nature of the OCS, BOEM also exercises independent judgment on what constitutes BACT and how it should be applied. This definition also clarifies that BACT, as used in this rule, is intended to refer to physical or mechanical controls (i.e., changes to the equipment and technology), in contrast to operational controls that would primarily involve changes in the ways that equipment is operated (rather than changes to the equipment itself). With reference to ‘‘the maximum extent practicable,’’ under certain circumstances, VOCs must be fully reduced to a rate at or below the EETs (including through the use of BACT) whether or not such a reduction would be considered practicable, unless emissions credits can be applied (see § 550.303(f)). In other words, under some circumstances a plan could not be approved because the level of VOC emissions would be too high, regardless of whether some ‘‘practical’’ method were available and if available was proposed to be applied to mitigate or reduce the emissions. In that rare instance, the only acceptable means to obtain approval of the plan would be for the lessee or operator to obtain emissions credits to offset the effects of the excessive VOC emissions. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Class I Area The current regulations use this term but do not define it. Because it is used more broadly in the proposed rule, BOEM proposes to define it in the regulations. The proposed rule would define this term to mean ‘‘an area designated by the USEPA, a State, or a Federally-recognized Indian tribe, where visibility and air emissions are protected by a Federal Land Manager, and protected to standards more stringent than the NAAQS pursuant to 42 U.S.C. 7472(a) or 7474, as amended; 76 Class I areas include international parks and certain national parks, wilderness areas, national monuments, and areas of special national or regional natural, recreational, scenic, or historic value.’’ Congress has established a program to designate specific areas of the country as Class I areas, and the USEPA defines these areas in its regulations at 40 CFR part 81 subpart D. Several tribes have 76 The USEPA’s guidance to tribes on Class I redesignations is available here: https://www3.epa.gov/ air/tribal/pdfs/ GuidanceTribesClassIRedesignationCAA.pdf. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 also requested USEPA to redesignate their lands from Class II to Class I to provide additional air quality protection.77 Class II Area Like the term ‘‘Class I area,’’ the current regulations use ‘‘Class II areas’’ but do not define the term. The proposed rule would define Class II area to mean ‘‘an attainment area designated by the USEPA, a State, or a Federallyrecognized Indian tribe, that is protected less stringently than a Class I area.’’ A Sensitive Class II area classification indicates a place the Clean Air Act would allow a moderate change in the air quality, but where stringent air quality constraints are nevertheless desired. This classification is less stringent than for a Class I area, which describes a place where minimal air quality degradation would be allowed, and more stringent than that of a Class III area, which indicates a place where substantial industrial or other growth would be allowed. Sensitive Class II areas (see definition of this term, below) represent a subset or sub-classification of Class II areas that are defined by federal land management agencies as federal lands where the protection of air resources has been prioritized, as specified in acts, regulations, planning documents, or by policy. Complex Total Emissions The proposed rule would define this new term to mean ‘‘the sum of the facility emissions that would result from all of the facilities that have been aggregated for the purposes of evaluating their potential consolidated impact on air quality, pursuant to the methodology set forth in § 550.303(d), and the sum of all corresponding attributed emissions for those facilities.’’ For the purposes of calculating complex total emissions, such emissions could include the emissions from pipeline vessels, bury barges, and lay barges during those periods of time while they are temporarily connected to the seabed on the OCS as long as these vessels meet the other requirements for complex total emissions consolidation. The proposed requirement to consolidate air emissions from multiple facilities in certain circumstances is described in more detail at the discussion of proposed § 550.303(d). 77 For example, the Northern Cheyenne Reservation, the Flathead Indian Reservation, the Fort Peck Indian Reservation, the Spokane Indian Reservation and the Forest County Potawatomi Community Reservation. See 40 CFR 52.1382(c), 52.2497(c) and 52.2581(f). PO 00000 Frm 00048 Fmt 4701 Sfmt 4702 Criteria Air Pollutant or Criteria Pollutant Criteria air pollutants are those pollutants for which the USEPA sets NAAQS. The proposed rule would add this new term (also referred to as criteria pollutant) (CP) to the proposed definitions section and would be defined to mean ‘‘any one of the principal pollutants for which the USEPA has established and maintains a NAAQS under 40 CFR part 50 and in accordance with 42 U.S.C. 7409, as amended, for the protection of public health and welfare.’’ The proposed rule clarifies that the USEPA has established primary standards for the protection of public health, including sensitive populations, and it has established secondary standards for the protection of public welfare from adverse effect, including those related to effects on vegetation, ecosystems, and visibility. The proposed rule would clarify criteria air pollutants do not include VOCs or any other precursor air pollutant not already regulated under the NAAQS. Precursor pollutants are defined under the definition of precursor air pollutant or precursor pollutant as explained later in this rulemaking. The proposed rule would define CP so it has the identical meaning as used by the USEPA. In those situations where BOEM intends for the proposed rule to refer only to CPs rather than all air pollutants, it has drafted the proposed rule so it specifically uses the term ‘‘criteria pollutant.’’ Design Concentration The proposed rule would define design concentration to mean ‘‘the pollutant concentration at a given location projected, through computersimulated air dispersion or photochemical modeling, as described under 40 CFR part 51, appendix W, section 7.2.1.1 to result from your projected emissions, combined with the background concentration for the same pollutant, averaging time, and statistical form at the most appropriate receptor location.’’ Each NAAQS has both an averaging time and a statistical form. The statistical form tells how the concentration level would be violated. For instance, the ‘‘statistical form’’ of the annual NO2 NAAQS is the annual mean measured over three years. The design concentration of any given CP is compared against the NAAQS in order to determine whether or not the activities in a proposed plan, together with the background concentrations, would exceed any NAAQS at any point landward of the SSB. The appropriate background concentration is measured E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules from the nearest point at which there is data from an USEPA-approved air monitoring system, or as determined on some other appropriate scientifically justified basis approved by BOEM. The design concentration of any given CP is compared against the NAAQS in order to determine whether or not the activities in a proposed plan would cause the concentration of that pollutant at any point landward of the SSB to exceed the level of the NAAQS. This approach takes into consideration the pre-existing ambient air concentration of that criteria air pollutant (i.e., the background concentration), as well as the increment added as a result of the emissions generated by operations associated with the proposed plan, in determining what the impact of the plan’s emissions will likely be at any given location. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Dispersion Modeling This new term would be defined to mean ‘‘the mathematical computer simulation of air emissions being transported from a source through the atmosphere under given meteorological conditions. Emissions from sources, expressed as the rate of air pollutants emitted over time (i.e., pounds per hour), are translated through computer modeling into pollutant concentrations, expressed in units of micrograms of pollutants per cubic meter of ambient air (mg/m3), or in parts per million or billion, depending on the circumstances.’’ The dispersion model must take various factors into account, including the amount of air emissions generated by the proposed facility and the relevant meteorological conditions that would apply at the proposed facility site, the nearby coast, and over submerged State lands. The proposed rule would clarify that when a file containing meteorological and emissions data are evaluated, the computer model is used to project the concentrations of the pollutants at a receptor location. Under the proposed subpart C of this part (‘‘Air Quality Analysis, Control, and Compliance’’), in the event that proposed operations exceed EETs, results of dispersion and photochemical modeling would be used to project the potential for a source to have a significant adverse effect on the air quality of a State onshore or at the SSB, and to discern whether the control of an individual emission source would have the desired effect of reducing the emissions’ impact for compliance with the AAQSB. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Emission Control Efficiency (ECE) This new term would be defined to mean the effectiveness of ERM for any given emissions source and air pollutant. The greater the emission control efficiency (ECE), the greater the relative effectiveness of the underlying controls. ECE measures effectiveness on a relative basis (i.e., as a percent of the pollution being reduced), rather than in absolute terms (i.e., the total reduction in the annual tonnage of the pollutant emitted). ECE varies from 100%, representing a control that completely eliminates emissions, to zero, representing a control that has no effect on such emissions. The proposed rule would describe the requirements relating to ECE at proposed § 550.309. Emissions Credits The proposed rule would supplement the use of the term ‘‘emissions offsets’’ with the broader term ‘‘emissions credits.’’ Emissions credits include emissions offsets as a subset. Emissions credits represent emissions reductions from emission sources that have nothing to do with the proposed plan or any facility or MSC associated with the plan. The definition of this term would be revised to mean ‘‘emissions reductions from an emissions source(s) not associated with the plan that are intended to compensate for the excessive emissions of criteria or precursor air pollutants, regardless of whether these emissions credits are acquired from an emissions source(s) located either offshore or onshore, including: (1) Emissions offsets generated by the lessee or operator directly; or (2) emissions offsets acquired from a third party; or (3) trading allowances or other alternative emission reduction method(s) or system(s) associated with a marketbased trading mechanism, such as a mitigation bank, or through other market oriented or competitive markets where these assets are exchanged.’’ Emissions credits are intended to compensate for excessive emissions associated with any given plan. The new term ‘‘emissions credits’’ is intended to have broader application than the existing defined term ‘‘emissions offsets.’’ The proposed definition is intended to account for any reduction in emissions from an emission source not associated with the plan, whereas the existing definition only includes reductions from facilities. The proposed defined term is used in subpart C to reflect a proposed change whereby an emissions reductions of an equivalent amount would be allowed in lieu of BACT or other emissions PO 00000 Frm 00049 Fmt 4701 Sfmt 4702 19765 reductions measures, regardless of whether such reductions are achieved on sources owned by the lessee or operator or a third-party or regardless of whether the reduction is obtained through the use of a market-based trading mechanism, such as a mitigation bank. USEPA operates a number of multi-State market-based emissions trading programs. Because these programs have broad geographic coverage, purchase of allowances from one of these programs would not be certain to reduce emissions from sources in any particular AQCR. The intent of the proposed requirement is that the purchase of emissions credits result in actual emissions reductions in the affected State. Consequently, such multi-State trading programs might not be an appropriate source of emission credits under the proposed rule. Emission Exemption Thresholds (EET) The proposed rule would define this term to mean ‘‘the maximum allowable rate of projected emissions, calculated for each air pollutant, expressed as short tons per year, above which facilities would be subject to the requirement to perform modeling.’’ The emission exemption threshold formulas are in proposed § 550.303. Emissions Factor(s) The proposed rule would define this term to mean a value that relates the quantity of a specific air pollutant released into the atmosphere with the operation of a particular emissions source. The proposed rule would clarify emissions factors are usually expressed as the mass of pollutant generated from each unit (e.g., mass, volume, distance, work, or duration) of activity by the emissions source emitting the pollutant. Emission Reduction Measure(s) (ERM) The proposed rule would define emission reduction measure(s) (ERM) to mean any emissions credit(s), operational control(s), equipment replacement(s), or BACT, applied on either a temporary or permanent basis, to reduce the amount of criteria or precursor air pollutant emissions that would occur in the absence of the application of such measures. Existing Facility The current regulations define this term as ‘‘an OCS facility described in an Exploration Plan or a Development and Production Plan submitted or approved before June 2, 1980.’’ The proposed rule would define this term to mean ‘‘an operational OCS facility described in an approved plan.’’ The existing definition is much narrower than the proposed E:\FR\FM\05APP2.SGM 05APP2 19766 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS one, because the existing definition is both limited to facilities described in EPs and DPPs (i.e., excluding DOCDs) and to those facilities described in plans submitted prior to June 2, 1980. Facility The proposed rule would revise the definition that exists in the current regulation. The proposed rule would define the term ‘‘facility’’ used in proposed § 550.205 and proposed subpart C to mean ‘‘any installation, structure, vessel, vehicle, equipment, or device that is temporarily or permanently attached to the seabed of the OCS, including but not limited to a dynamically positioned ship, gravitybased structure, manmade island, or bottom-sitting structure, whether used for the exploration, development, production, or transportation of oil, gas, or sulphur.’’ The proposed rule would specify all installations, structures, vessels, vehicles, equipment, or devices directly associated with the construction, installation, and implementation of a facility would be considered part of a facility while located at the same site, attached, or interconnected by one or more bridges or walkways, or while dependent on, or affecting the processes of, the facility, including any ROV while attached to the facility. The proposed rule would also specify that one facility may include multiple drill rigs, drilling units, vessels, platforms, installations, devices, and pieces of equipment. Also, under the proposed rule, MODUs, even while operating in the ‘‘tender assist’’ mode (i.e., with skid-off drilling units), and any other vessel engaged in drilling or downhole operations, including wellstimulation vessels would be treated as facilities for purposes of evaluating air emissions. Under the proposed rule, the term would also include all Floating Production Systems (FPSs), including Column-Stabilized-Units (CSUs), Floating Production, Storage and Offloading facilities (FPSOs), TensionLeg Platforms (TLPs), and spars. The proposed rule would also provide any vessel used to transfer production from an offshore facility be considered part of the facility while physically attached to it. Finally, the proposed rule would specify all DOI-regulated pipelines be considered facilities, as would be any installation, structure, vessel, equipment, or device connected to such a pipeline, whether temporarily or permanently, while so connected. The proposed rule would therefore require both lease-term pipeline installations and right-of-way pipeline installations to comply with BOEM’s air quality regulations. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 The current regulation defines facility, as used in subpart C, as: ‘‘[A]ny installation or device permanently or temporarily attached to the seabed which is used for exploration, development, and production activities for oil, gas, or sulphur and which emits or has the potential to emit any air pollutant from one or more sources. All equipment directly associated with the installation or device shall be considered part of a single facility if the equipment is dependent on, or affects the processes of, the installation or device. During production, multiple installations or devices will be considered to be a single facility if the installations or devices are directly related to the production of oil, gas, or sulphur at a single site. Any vessel used to transfer production from an offshore facility shall be considered part of the facility while physically attached to it.’’ The proposed definition would be similar to the current definition in at least two ways. First, an onshore facility or onshore support facility would not constitute a ‘‘facility’’ under the proposed definition. Second, under the proposed rule one facility might include multiple drill rigs, drilling units, vessels, platforms, installations, devices, and pieces of equipment. The proposed rule would generally reorganize the substance of the current definition and provide examples and more explanatory text. In addition, there are several notable substantive changes proposed. First, the proposed rule would revise the definition by eliminating the requirement that a facility ‘‘emit or have the potential to emit any air pollutant from one or more sources.’’ This limitation could have been read to imply that, for example, since sub-sea tiebacks and other subsea devices do not themselves emit air pollutants, vessels engaged in installing them were not facilities even though they were connected to the seabed of the OCS. Removing this limitation would make clear that any vessel which is temporarily or permanently attached to the seabed such as a well-stimulation vessel or a pipeline laying vessel connected via a subsea tieback, would be considered a facility for the purposes of evaluating air emissions. Such a vessel would be considered an MSC when not attached to the seabed. The current definition was developed when wells were drilled individually and generally connected separately to distinct production platforms. Now, many wells can be drilled and connected to a single production facility from significant distances, because subsea tiebacks are becoming increasingly viable, both technically and PO 00000 Frm 00050 Fmt 4701 Sfmt 4702 economically. Similarly, under the proposed rule, the same principle would apply to any structure or vessel that is connected to a pipeline or which is laying a pipeline. Second, whereas the existing definition specifies facilities are ‘‘used for exploration, development, and production activities,’’ the proposed rule would add ‘‘transportation’’ to this list. This change is intended to make the definition track the language in OCSLA Section 4(a), which includes installations and devices used for the purposes of transporting oil and gas. This change would also reflect the fact the definition now explicitly covers pipelines, which, though they do not themselves normally emit air pollutants, are the means by which vessels that do emit air pollutants are connected to the OCS. The third change would specify more clearly any equipment directly associated with a facility is considered part of that facility if it is dependent on, or affects the processes of, that facility. The existing definition contains the provision: ‘‘During production, multiple installations or devices will be considered to be a single facility if the installations or devices are directly related to the production of oil, gas, or sulphur at a single site.’’ The proposed definition would remove the references to production. Instead it would provide: ‘‘All installations, structures, vessels, vehicles, equipment or devices directly associated with the construction, installation, and implementation of a facility are part of a facility while located at the same site, attached, or interconnected by one or more bridges or walkways, or while dependent on, or affecting the processes of, the facility.’’ As a consequence of these changes, mobile sources of emissions would generally be considered part of the facility only while attached to a facility, and not part of the facility otherwise. However, while these mobile sources, such as ice breakers and other support vessels, would not usually be considered part of a facility, and therefore not regulated by BOEM as a facility, their emissions would be accounted for and reported as attributed emissions and would be evaluated to determine whether a proposed plan would cause a potential impact to a State’s air quality and could, therefore, trigger a requirement to apply controls in accordance with the requirements of subparts B and C of this part. Facility Emissions The proposed rule would define this new term to mean, ‘‘for any given criteria or precursor air pollutant, the E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules annual rate, the maximum 12 consecutive month rolling sum, and the peak hourly emissions from all emissions sources on or connected to a facility’’ (to be consistent with the State permit applications and consistent with the standards for hourly NAAQS, as set by the USEPA). Emissions data required to evaluate compliance with other NAAQS with averaging periods between 1 year and 1 hour, such as the 24-hour PM10 and PM2.5 NAAQS and the and rolling 3-month Pb NAAQS would be estimated by applying temporal allocation factors to annual emissions modeling, rather than by requiring facilities to also provide emissions information for each of these averaging periods. As described in proposed § 550.205, under the proposed rule, facility emissions along with attributed emissions would constitute projected emissions. Fugitive Emissions The proposed rule would define this new term to mean the emissions of an air pollutant from an emissions source that do not pass through a stack, chimney, vent, or other functionally equivalent opening. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Fully Reduce(d) The proposed rule would define this term to mean ‘‘to decrease emissions of VOCs to a rate that will not exceed the emission exemption threshold calculated under subpart C § 550.303(c), or to decrease emissions of criteria air pollutants to a rate that will cause ambient impacts that do not exceed the Significant Impact Levels set out in the table in 40 CFR 51.165(b)(2), as amended.’’ Long-Term Facility The proposed rule would define this term to mean a facility that remains at the same general location for three years or longer. Under the current regulations, there is a definition for temporary facility, but no corresponding one for long-term facility. Thus, although the definition is new, the concept underlying the use of this term has been in existence for many years. There are two notable aspects of the proposed definition. First, the definition would specify a facility located on the same lease block or within one nautical mile of its original location is still considered to be in the same location for purposes of the air quality evaluation. Second, once a facility becomes attached to the sea floor and is used for drilling, production, or transportation, it would be considered to be ‘‘in use.’’ The fact it might not be used for the entire year does not mean BOEM should not VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 consider it to be located at a site for the year. For example, under the proposed rule, a facility that is located at a site for three months, then removed and later put back into service at the same location the next year would be considered in use at that location for two years. Likewise, under the proposed rule, a facility that drills on the same block for three months in each of ten years would be considered a long term facility because it is operating at the same location for more than three years; it would not be a short term facility by virtue of the fact it is only physically located in the block for a total of thirty non-contiguous months. If a facility must move from the location where it first attached to the seabed due to adverse weather or other conditions over which the lessee or operator had no control, the proposed § 550.313(b) would allow the Regional Director to extend the time for which a facility could avoid being classified as a long-term facility by the number of months during which a lessee or operator is unable to operate at that location. Major Precursor Pollutant The proposed rule would define this new term to mean any precursor pollutant for which the States are required to report actual emissions to the USEPA, as defined in 40 CFR 51.15(a). MARPOL-Certified Engine 78 The proposed rule would define this new term to mean ‘‘either: (1) An engine with a power output of more than 5,000 kW and a per cylinder displacement at or above 90 liters installed on a ship constructed on or after 1 January 1990 but prior to 1 January 2000 that is subject to Regulation 13.7 of MARPOL Annex VI; or, (2) an engine with a power output of more than 130 kW built on or after January 1, 2000 that is subject to Regulations 13.1 through 13.6 of MARPOL Annex VI. According to USEPA, a MARPOL engine operated aboard a U.S. vessel must have a U.S.-issued Enhanced International Air Pollution Prevention for each engine, as well as the relevant Certificate of Compliance from the USEPA. 78 Note that the USEPA requires that each MARPOL engine installed on a U.S. vessel that operates internationally must have a USEPA-issued Engine International Air Pollution Prevention (EIAPP) certificate as well as the relevant Certificate of Compliance to the applicable CAA standards also issued by the USEPA. PO 00000 Frm 00051 Fmt 4701 Sfmt 4702 19767 Maximum Rated Capacity The proposed rule would define this new term to mean ‘‘the maximum power an engine is capable of generating, expressed in kW, and if necessary, as converted from mechanical horsepower (hpm, where 1 hpm of power equals 745.699872 W or 0.745699872 kW) or from the International Table values of British thermal units (BtuIT, where 1 BtuIT/hour of power equals 0.29307107 Watts or 0.00029307107 kW).’’ For the purposes of determining whether a proposed facility should be exempt from modeling, the current regulation requires the reporting of projected emissions based on ‘‘the maximum rated capacity of the equipment on the proposed drilling unit under its physical and operational design’’ 30 CFR 550.218(a)(3). Under the proposed rule, this requirement would apply to all engines, not just the drilling unit, because the emission inventory will also include attributed emissions sources (§ 550.205(c) and (d)). The proposed rule, at § 550.205(d)(2)(ii), is aimed at estimating maximum emissions that could occur given the engines that will be used, under any operating constraint proposed by the source. This will involve determining the type of engine operation that produces the highest emissions per hour of operation, which for some pollutants will not be operation at maximum rated capacity. However, even in such a case, information on the maximum rated capacity will be useful for converting ‘‘percent of rated capacity’’ into actual engine loads and therefore emissions, and for generally documenting the types and sizes of engines that will be operating as part of the planned activities. The proposed definition of maximum rated capacity would specify that that maximum rated capacity must be expressed in kW, or converted from hpm, or British thermal units per hour from the International Tables (BtuIT), since that is the most standard measure for power. In contrast, the term horsepower (hp) has many values, including mechanical hp, electric hp, international hp, metric hp, boiler hp, or water hp. Because there is no standard unit for hp—the range of equivalency is 735.5 watts to 750 watts; BOEM is proposing to use kW instead. Using kW would facilitate converting measurements and would ensure the use of one consistent standard, International System of Units (SI), in kilowatts. Also, using kW would eliminate the reporting or misreporting of hp based on the many types of hp that can be used for various purposes E:\FR\FM\05APP2.SGM 05APP2 19768 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules and, thereby, improve the accuracy of the reports and information submitted to BOEM.79 National Ambient Air Quality Standards (NAAQS) The proposed rule would define this term to mean ‘‘the ambient air standards established by the USEPA, as mandated by the CAA (42 U.S.C. 7409), set out in 40 CFR part 50, for the criteria air pollutants considered harmful to public health or welfare when concentrations are elevated over time.’’ The proposed definition would explain that the NAAQS consist of two categories, both of which are included within the defined term: Primary standards that set limits to protect public health, including the health of ‘‘sensitive’’ populations such as asthmatics, children, and the elderly; and secondary standards that set limits to protect public welfare, including protection against visibility impairment, prevention of harm to animals, including marine mammals, fish and other wildlife, and avoidance of damage to crops, vegetation, and buildings. Non-Attainment Area asabaliauskas on DSK3SPTVN1PROD with PROPOSALS The proposed rule would revise the definition that exists in the current regulation to mean, for any given criteria air pollutant, a geographic area, which the Administrator of the USEPA has determined exceeds a primary or secondary NAAQS, as codified at 40 CFR part 81 subpart C. A designated ‘‘non-attainment area’’ is defined in the current rule as, ‘‘for any given criteria air pollutant, an area which is shown by monitored data or which is calculated by air quality modeling (or other methods determined by the Administrator of [US]EPA to be reliable) to exceed any primary or secondary ambient air quality standard established by [US]EPA.’’ This revision is necessary because the existing definition does not clarify that any given area may be designated as an attainment area for one criteria air pollutant and yet be a designated non-attainment area for another criteria air pollutant. 79 Units called ‘‘horsepower’’ (hp) have differing definitions: There is mechanical hp, also known as imperial hp, of exactly 550 foot-pounds per second (approximately equivalent to 745.7 watts); metric hp of 75 kg-m per second (approximately equivalent to 735.5 watts or 98.6% of an imperial mechanical hp); boiler hp used for rating steam boilers (equivalent to 34.5 pounds (about 15.6 kg) of water evaporated per hour at 212 degrees Fahrenheit (100 degrees Celsius), or 9809.5 watts); electric motor hp (equal to 746 watts); and British Royal Automobile Club (RAC) hp is one of the tax hp systems adopted around Europe which make an estimate based on several engine dimensions (using a conversion rate of 0.735 kW for 1 hp). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Operational Control(s) The proposed rule would define this term to mean a process, method, or technique, other than a physical or mechanical control or equipment replacement, that reduces the emissions of criteria or precursor pollutants (e.g., limitation on period of operation, load balancing, use of less-polluting fuels, and/or operating equipment at less than full capacity). Operational control(s) would include, but not be limited to, operating a vessel or facility for a limited number of hours per day, limiting the total amount or type of fuel used over a period of time, load balancing or operating equipment at some level less than full capacity. Particulate Matter (PM) The proposed rule would define this new term to mean ‘‘an airborne contaminant consisting of particulate matter that is regulated as a criteria air pollutant under the ambient air standards.’’ The proposed rule would explain that PM10 refers to airborne contaminants of particulates less than or equal to 10 micrometers. PM10 is distinct from coarse PM in that coarse PM consists of particulate matter equal to or less than 10 micrometers but greater than 2.5 micrometers. Further, it would explain PM2.5, or fine PM, is an airborne contaminant of particulates less than or equal to a diameter of 2.5 micrometers. rather than the actual emissions of a stationary source. In this proposed rule, the term facility emissions is generally used to refer to the emissions of sources regulated under BOEM’s AQRP, whereas PTE is used to refer to the emissions of sources not regulated by BOEM. Potential to emit means the maximum capacity of a source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the source to emit a pollutant including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, shall be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable. Attributed emissions 80 do not count in determining the PTE of a stationary source. Precursor Air Pollutant or Precursor Pollutant The proposed rule would add this new term to mean ‘‘a compound that chemically reacts with other atmospheric gases to form a criteria air pollutant.’’ The proposed definition notes some precursor air pollutants are also defined as criteria air pollutants. The proposed definition would also explain precursor air pollutants include VOCs, NOX, SO2, and NH3. Plan The proposed rule would add this term to the definitions section to mean ‘‘any initial, revised, modified, resubmitted, or supplemental Exploration Plan (EP), or DPP, DOCD, or application for a Right-of-Use and Easement (RUE), a Pipeline ROW, or lease term pipeline.’’ The term ‘‘plan’’ is used throughout proposed § 550.205 and proposed subpart C, and this definition would make explicit it is intended to refer to all plans, regardless of whether a plan is for exploration or development or whether it is an initial plan or a revised, modified, resubmitted, or supplemental plan. For simplicity, where the term plan is used in proposed § 550.205 or proposed subpart C, the specific requirement would be equally applicable to all types of plans. Projected Emissions Potential To Emit The definition of ‘‘potential to emit’’ is derived from the USEPA regulations at 40 CFR 51.301. In this proposed rule, the term is used in a manner similar to that of the term ‘‘facility emissions.’’ Both terms are meant to describe the measure of the maximum potential Proximate Activities PO 00000 Frm 00052 Fmt 4701 Sfmt 4702 The proposed rule would define this new term to mean ‘‘for any given criteria or precursor air pollutant, the sum of one facility’s emissions and its corresponding attributed emissions over the specified time period, with the controlled or uncontrolled nature of the pollutants specified by the context.’’ Projected emissions include the attributed emissions from offshore vessels and offshore vehicles that support a facility. The individual pollutants included among the projected emissions may be reported on an annual basis or as peak-hour projected emissions, and may be either uncontrolled or controlled and may or may not require the use of BACT, emissions credits, or other ERM from any source(s) as described in § 550.205(e) and (f). The proposed rule would define this term to mean ‘‘activities that involve or affect any of the following: The same 80 The USEPA refers to attributed emissions as secondary emissions, which it defines in 40 CFR 52.21. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules well(s); a common oil, gas, or sulphur reservoir; the same or adjacent lease block(s); or, facilities located within one nautical mile of one another.’’ The proposed definition would also specify that, where a well is drilled from one facility, but production from the well will ultimately take place through a different facility, the drilling and production activities constitute proximate activities if they occur within the same twelve-month period. The proposed rule would define this new term to mean ‘‘a Class II area defined by an FLM agency as being federal land where protection of air resources has been prioritized, as specified in acts, regulations, planning documents, or policy.’’ Agencies with land management responsibility commonly refer to federal land areas that are not Class I areas but are environmentally sensitive as sensitive class II areas. Although the USEPA has not defined different air quality standards or benchmarks for sensitive Class II areas, Federal Land Managers give special attention and subject sensitive Class II area to a more extensive air quality review than would normally be accorded to a typical Class II area. In the context of this rule, an important example of a sensitive Class II area would be the Arctic National Wildlife Refuge in Alaska. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Short-Term Facility This new proposed term would replace the term ‘‘temporary facility’’ in current § 550.302. The proposed rule would use this new term with a similar but expanded meaning. The proposed definition has been expanded so now any facility that is not a long-term facility or is not connected to such a facility would be considered a shortterm facility. If a facility must move from the location where it first attached to the seabed due to adverse weather or other conditions over which the lessee or operator had no control, the proposed § 550.313 would allow the Regional Director to extend the time for which a facility could be classified as a shortterm facility by the number of months during which a lessee or operator is unable to operate at that location. BOEM recognizes that the USEPA classifies a short-term facility as being a facility that is located at the same location for no more than two years and solicits comments on the implications of retaining or potentially changing this longstanding practice. VerDate Sep<11>2014 22:26 Apr 04, 2016 Significant Impact Level (SIL), or Significance Level Paragraph 550.303(b)—Calculating Projected Emissions The proposed rule would define these terms to mean ‘‘an ambient air benchmark that applies to the ambient air impact of the emissions of a criteria air pollutant, as set out in the table in 40 CFR. 51.165(b)(2).’’ The terms ‘‘significant impact level’’ and ‘‘significance level’’ mean the same thing and are interchangeable. These paragraphs would establish the requirement that a lessee or operator must compare its projected emissions or its complex total emissions with the applicable EETs. More detailed requirements for calculating and reporting projected emissions, facility emissions, and attributed emissions are set forth in proposed § 550.205 and explained in the preamble discussion regarding that provision. Technically Feasible Sensitive Class II Area Jkt 238001 19769 The proposed rule would define this new term to mean ‘‘a technology or methodology that: (1) Has been demonstrated and operated successfully on the same type of emissions source as the one under review; or (2) is available and applicable to the type of emissions source under review.’’ BOEM solicits comments on whether the technical feasibility should have to be demonstrated for the particular source identified in the plan or whether the feasibility could be demonstrated through use of similar but different sources. Total Support Emissions The proposed rule would define this new term to mean ‘‘for any criteria or precursor air pollutant, the total emissions generated by an MSC that operates in support of your and any other facilities, for the 12-month period over which the corresponding facility emissions are measured.’’ Proposed § 550.205(d) would set forth an example for calculating total support emissions. Section 550.303—What analysis of my projected emissions is required under this subpart? Section 550.303(a)—Establishing Emission Exemption Thresholds BOEM establishes emission exemption thresholds (EETs). BOEM would define EETs as the maximum allowable rate of projected emissions, calculated for each air pollutant, above which facilities would be subject to the requirement to perform modeling. These EETs would establish those levels of consolidated emissions below which BOEM has determined would not cause or contribute to a violation of the NAAQS. The proposed rule would provide that, if projected emissions or complex total emissions are exempt, then the lessee or operator would not be required to perform air quality modeling in accordance with the requirements of proposed § 550.304 of this subpart and to apply any controls, as described in proposed §§ 550.305 through 550.307. PO 00000 Frm 00053 Fmt 4701 Sfmt 4702 Paragraph 550.303(c)—Emission Exemption Threshold(s) Under the proposed rule, BOEM would determine whether the lessee or operator’s projected emissions or complex total emissions have the potential to significantly affect the air quality of any State, in accordance with the EETs calculated under this proposed paragraph. This paragraph would provide that BOEM will, sometime after the rule is finalized, publish updated EETs in the Federal Register. These thresholds would be based on criteria proposed in this rule and would fall within a range proposed in this rule. Under the proposed rule, until such time as BOEM has published these new EETs in the FR (herein referred to as the date of the Notice) 81 and has solicited public comment thereon, a lessee or operator’s projected emissions or complex total emissions would be exempt if its projected emissions or complex total emissions are below the EETs set in the current regulation at § 550.303(d). During this period, the distance variable in these formulas would continue to be the shortest distance of the facility to the shoreline, as is the case under the current rule. The proposed rule would require BOEM to provide notice of proposed EETs in the FR, and an opportunity to comment on them, any time it subsequently issues new EETs or revises existing ones. The proposed rule would establish the process BOEM would follow to provide notice of proposed EETs in the FR, and an opportunity to comment on them, any time it subsequently issues new EETs or revises existing ones. BOEM anticipates that it would establish new EETs based on the EET studies currently underway and would publish these in the FR after the completion of the studies (estimated in 2020). BOEM would then require that all future plans be evaluated in terms of their effects on the air quality of neighboring States by considering the impacts landward of the SSB (including 81 Estimated E:\FR\FM\05APP2.SGM to take place in 2020. 05APP2 19770 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS the air above the State’s submerged lands, at the shoreline and inland of the shoreline). New EETs for those pollutants added to this proposed rule will not be established until such time as the relevant studies have been completed. Section 550.303(c)(2) of the proposed rule provides criteria that BOEM would use to determine the formulas that BOEM would publish in the FR. These include: The absolute level of projected emissions; the distance of the proposed facility or facilities from any State or from critical natural resources, animals, and habitats; the existing ambient air pollution in potentially affected States; the trend in the ambient air pollution in those States; the associated attainment status of such areas and the associated effects to public health and welfare; any USEPA AAQSB applied by this proposed rule; the types, frequency and duration of any air pollutant emissions and their formation and/or dispersion characteristics; the characteristics of the facility or facilities and MSCs, including the type and nature of the emissions sources, and the height of the associated emission points or stacks; the prevailing meteorological characteristics in any given area, including air stability, relevant wind speeds and directions; the amount of emissions from existing facilities and vessels in the vicinity of the proposed facility; and other necessary and appropriate conditions. Several of these criteria (used to determine the EETs) are localized and may differ according to area even within one OCS region (e.g., prevailing meteorological characteristics and the amount of emissions from existing facilities and vessels in the vicinity). Accordingly, BOEM expects that the EETs it would set in the FR would vary from area to area. This could result in different sets of formulas for each planning area or smaller geographic unit. The proposed rule also would establish a range within which these new EET formulas will apply. Above this range, lessees and operators would VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 always be required to perform air quality modeling, in accordance with the requirements of § 550.304 of this subpart, or to apply controls, as described in §§ 550.305 through 550.307, and below this range lessees and operators would not be required to do so. Within this range, lessees and operators would be exempt from these requirements only if their projected or complex total emissions were below the EETs defined by the formulas BOEM will publish in the FR. Proposed § 550.303(c)(3)(ii) would set the upper boundary of this range. The proposed subparagraph would set the upper bounds of this range with the current EET formulas (currently codified at 30 CFR 550.303(d)). However, the distance variable in the formulas would be measured from the closest point on the SSB.82 Because this feature of the upper boundary formulas would allow the upper boundary to vary all the way down to zero (when the distance is zero), BOEM is proposing to set constant values for the EETs for facilities within the first three nautical miles of the State’s seaward boundary. These proposed values would be based on the current values of the current emission exemption formulas at the SSB, and, for all pollutants other than CO, they would correspond to the 100 tpy major source criteria from the USEPA NSR permitting program, as defined in its regulations at 40 CFR part 70.83 Chart II, below, depicts how the current thresholds would shift to become the upper boundaries of the 82 Because these same formulas would also serve as the EETs during the period after the rule is finalized and before the new formulas are established in the FR, subparagraph (4)(i) sets forth the same formulas as (4)(ii) but defines the distance variable as the distance from the shoreline. 83 The USEPA has two thresholds used to determine what constitutes a major source for purposes of its permitting program. In addition to the 28 source categories for which the 100 tpy threshold applies, the USEPA has a 250 tpy threshold that applies to other source categories. BOEM’s existing exemption thresholds were originally based on the 100 tpy standard and BOEM has elected to retain this as the criteria, since it is a more conservative approach. PO 00000 Frm 00054 Fmt 4701 Sfmt 4702 range once BOEM publishes the future thresholds in the Federal Register. The highest series represents the current thresholds, while the two lower series represent the EETs that would apply to those States with three and nine nautical mile State submerged land boundaries, respectively. At the present time, BOEM does not have EETs for Pb, PM2.5, or PM10, nor has it established EETs that would apply to anything other than the projected annual emissions. Until such time as EETs are established for these pollutants, no plan would be required to model on the basis of their emissions of these pollutants alone (except for Pb, for which the proposed rule would set an EET which could trigger a requirement for modeling). BOEM recognizes there may be a more appropriate distance-adjusted maximum emission exemption threshold for these pollutants and solicits comments from stakeholders on what they should be. Any comments should include an analysis of the reasoning used to support an alternative threshold, keeping in mind that the key goal is to ensure that offshore projected emissions of Pb, PM2.5, or PM10 do not ‘‘cause or contribute to a violation’’ of their corresponding NAAQS. Proposed § 550.303(c)(3)(i) would set the lower boundary of this range. The proposed formulas for these minimums represent emissions levels below which the ambient air impact at the nearest point in a State would not exceed any annual SIL. To derive these equations BOEM used a Gaussian dispersion equation, setting the concentration variable of the equation equal to a SIL and solving for the corresponding emissions rate. An example of the theoretical model underlying this analysis is provided for illustration purposes below: 84 84 BOEM Alaska OCS Region, 2015, Chukchi Sea Planning Area Oil and Gas Lease Sale 193 in the Chukchi Sea, Alaska Final Second Supplemental Environmental Impact Statement BOEM 2014–669. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules 19771 Chart 1: Gaussian Dispersion Model: Gaussian e In deriving these equations BOEM used conservative assumptions regarding the wind speed, stack height and air stability. For a full description of the method used to derive these equations see the Appendix: BOEM VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Analysis of Minimum Emission Exemption Thresholds available in the rulemaking docket at www.regulations.gov. If you have questions concerning the analysis done regarding the formulas or PO 00000 Frm 00055 Fmt 4701 Sfmt 4702 analysis related to the minimum emission exemption thresholds, you may contact Virginia Raps of the BOEM Alaska OCS Regional Office, by mail at the Bureau of Ocean Energy Management, Alaska OCS Region, 3801 E:\FR\FM\05APP2.SGM 05APP2 EP05AP16.004</GPH> asabaliauskas on DSK3SPTVN1PROD with PROPOSALS H 19772 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules maximum exemption threshold, and the proposed minimum exemption threshold for NOX. The chart shows that the proposed maximum threshold would have the same slope as the current threshold but would shift slightly lower due to proposed rule’s changing the ‘‘distance’’ variable to be measured from the SSB. The space inbetween the proposed maximum and the proposed minimum represents the range where BOEM would apply the formulas it will publish in the Federal Register. Section 550.303(c)(3)(i) lists the formulas for the proposed new minimum emission exemption thresholds for those CPs for which the USEPA has established SILs. Paragraph 303(c)(ii) would include a minimum emission exemption threshold for Pb. To establish a minimum emissions exemption level for Pb, the proposed rule would adopt the USEPA significant emissions rate for Pb, as described in USEPA regulations at 40 CFR 52.21(b)(23)(i). This amount is currently set at 0.6 short tons of emissions per year. BOEM is proposing this addition in order to ensure consistency with USEPA regulations and to ensure all OCS facilities comply with the requirements of OCSLA. BOEM is not proposing to establish a distance-based formula for Pb because the USEPA has not established SILs for Pb which would enable BOEM to apply the above methodology. Instead, BOEM is proposing to utilize the USEPA’s significant emissions rate for Pb as an emissions threshold. As an alternative to the proposed distance-based formula, BOEM is also considering an option in which it would establish new minimum EETs based on the PSD emissions limits in the USEPA’s regulations at 40 CFR 52.21(b)(23)(i). Those USEPA tables are intended primarily to determine whether a facility will generate potentially significant incremental increases in pollutant concentrations in the area surrounding the proposed 85 This chart would apply to all CPs other than CO, ozone and lead. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00056 Fmt 4701 Sfmt 4702 E:\FR\FM\05APP2.SGM 05APP2 EP05AP16.005</GPH> asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Centerpoint Drive, Suite 500, Anchorage, AK 99503, or by email at Virginia.Raps@boem.gov, or by phone at (907) 334–5200. The following chart illustrates the proposed emission exemption thresholds for NOX. It shows the current exemption threshold, the proposed Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS emissions source. BOEM could either apply the current absolute numbers or utilize the values in the USEPA table and adjust them, on either a linear basis or on the basis of a Gaussian dispersion equation, in an appropriate manner based on the distance of the facility from the State. BOEM solicits comments on this and other possible alternative approaches to establishing new maximum EETs (above which all plans would be subject to modeling) and minimum EETs (below which BOEM would not establish any new EETs).86 Such a discussion would ideally include information both on the levels of the two sets of formulas, as well as on the type and nature of the formulas that should be applied. Finally, because the NAAQS are subject to change as scientific knowledge improves and because technical and modeling capabilities may improve over time, the proposed rule provides that BOEM, at its discretion, would revise the emission exemption thresholds on an ongoing basis either as a result of a change in an applicable standard or because BOEM’s ability to measure and evaluate the impact of existing emission exemption thresholds has improved or for some other reason. Thus, under the proposed rule, if the USEPA revises the NAAQS, or any applicable SIL or AAI, BOEM would examine the appropriateness of its emission exemption thresholds, and, BOEM, at its discretion, could periodically revise its exemption formula(s) or its exemption threshold amount(s) for the corresponding air pollutant(s), as appropriate. Paragraph 550.303(d)—Consolidation of Air Pollutant Emissions From Multiple Facilities The purpose of this section is to determine whether two or more facilities wholly or partially owned, controlled or operated by the same entity that are located in relatively close proximity may collectively cause or contribute to a violation of any relevant air quality standard or benchmark, even if they would not do so when considered on a separate basis. The proposed rule would require projected emissions from multiple facilities under common ownership to be combined for analysis and reported as complex total emissions under certain circumstances. BOEM’s current practice is to require, in specific circumstances, the consolidated 86 With the adoption of the new EETs, there would be no need for any lessee or operator to review or evaluate their emissions as compared to the minimum thresholds because those minimums will, in all cases, be below the EETs. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 analysis of facilities covered by multiple plans in accordance with the following provision of § 550.303(j): ‘‘If, during the review of a new, modified, or revised Exploration Plan or Development and Production Plan, the Regional Supervisor determines or an affected State submits information to the Regional Supervisor which demonstrates, in the judgment of the Regional Supervisor, that projected emissions from an otherwise exempt facility will, either individually or in combination with other facilities in the area, significantly affect the air quality of an onshore area, then the Regional Supervisor shall require the lessee to submit additional information to determine whether emission control measures are necessary.’’ The current regulations do not specify under what circumstances the Regional Supervisor would make such a determination. This proposed paragraph recognizes the fact that emissions from two or more OCS facilities located in close proximity to one another may have an impact on the air quality of a State, when operated contemporaneously, even in those situations where the emissions from any one of those facilities, when compared against the emission exemption thresholds, would indicate that that facility should not cause an adverse impact to the air quality of a State. Closely-grouped facilities that emit pollutants at the same time can affect the air quality of a State differently than facilities that are spread across a larger area. The proposed rule would require a lessee or operator to add together its projected emissions with the emissions from other facilities whether or not they are described in lessee or operator’s plan and whether they currently exist or are proposed. The proposed paragraph would specify the conditions under which a lessee or operator would be required to consolidate the projected emissions from multiple facilities. Under the proposed rule, projected emissions from multiple facilities would be required to be consolidated if: (1) The emissions from multiple facilities are generated by proximate activities (i.e., the same well(s); a common oil, gas, or sulphur reservoir; the same or adjacent lease block(s); or, by facilities located within one nautical mile of one another); (2) the lessee or operator wholly or partially owns, controls or operates those facilities; (3) the construction, installation, drilling, operation, or decommissioning of any of the lessee or operator’s facilities occurs within the same 12-month period as the construction, installation, operation, or decommissioning of another facility that PO 00000 Frm 00057 Fmt 4701 Sfmt 4702 19773 meets conditions 1 and 2; and (4) such a consolidation of emissions from multiple facilities would generate emissions sufficient to exceed an applicable emission exemption threshold. If any two or more facilities meet all of the conditions specified in paragraphs (d)(1)(i) through (iv) of this proposed section the lessee or operator would be required to calculate the sum of the projected emissions from those facilities (including its respective attributed emissions), as the complex total emissions for its plan. If there are two or more facilities that would normally be submitted in one plan, and which are intended to be part of one unit or project, those facilities should be evaluated together. This requirement is intended to discourage submission of multiple plans for the purpose of remaining under the exemption thresholds. This requirement would be applied only to facilities that are wholly or partially owned, controlled or operated by the same party. This limitation is intended to further ensure that the associated air quality analysis would be applied consistently across projects, regardless of whether a lessee’s or operator’s project is submitted for approval in one plan or whether it submits several plans separately. According to BOEM regulations (in § 550.105), a lessee is defined as being ‘‘a person who has entered into a lease with the United States to explore for, develop, and produce the leased minerals. The term lessee also includes the BOEM-approved assignee of the lease, and the BOEM-approved sublessee of operating rights in the lease.’’ The definition of ‘‘you’’ includes a ‘‘lessee, the owner or holder of operating rights, a designated operator or agent of the lessee(s), a pipeline ROW holder, or a State lessee granted a right of use and easement.’’ Thus, the requirement for common ownership of a facility would extend to the lessee or their assignee as well as to those that share other lease interests, including joint ownership in a common unit, joint operating rights interests, as well as companies that use the same designated operator or unit operator for those facilities located in the same general vicinity of the proposed new facility. In order to determine common ownership, BOEM will rely on the criteria defined by the Office of Natural Resources Revenue (ONRR) for evaluating whether or not two companies should be considered affiliates, as defined in the regulations at 30 CFR 1206.101 and 30 CFR 1206.151. BOEM solicits comments from lessees E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19774 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules and operators with respect to how it could most effectively limit the application of these consolidation criteria to relevant parties and avoid the consolidation of emissions associated with facilities that are operated by unaffiliated companies. Facilities whose projected emissions would have been consolidated but for the exemption related to ownership and control would still be evaluated for their consolidated effects to the States outside of the AQRP. BOEM will conduct independent studies regarding the consolidated effects of multiple facilities on the air quality of the neighboring States and will also evaluate the potential for future cumulative impacts in conjunction with the associated NEPA review of the FiveYear Oil and Gas Leasing Program, the associated lease sales and the lease sale EISs. The proposed paragraph would also specify that if all of the emissions to be combined relate to the lessee’s or operator’s wholly-owned facilities, then the lessee or operator would be required to provide the data and analysis regarding the complex total emissions. However, where the lessee or operator does not fully own all of the facilities whose projected emissions are to be consolidated, the lessee or operator would need to gather data either from the operator of any facilities that it does not wholly own or which it does not operate, or from the publically available database of plans approved by BOEM, and would need to provide all the data and analysis it gathered. BOEM would make a determination whether the lessee or operator has appropriately considered the relevant data in its analysis of the complex total emissions. If all of the emissions to be combined relate to the lessee or operator’s whollyowned facilities, that lessee or operator must provide all the data and analysis of the complex total emissions. Under the proposed rule, if any lessee or operator were required to consolidate projected emissions data from multiple facilities, then anywhere a proposed requirement is written to apply to projected emissions that proposed requirement would instead apply to complex total emissions, except with respect to the process by which projected emissions are determined for any given facility (as specified in § 550.205(c), (d), and (e)). Paragraphs 550.303(e) and (f)— Emissions Do Not Exceed any Threshold or Exceed a Threshold The purpose of these two paragraphs is to determine whether the facility or facilities covered by a proposed plan VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 should be required to do modeling to determine whether, or to what extent, its operations might adversely affect the air quality of a State. If a plan is proposed that would result in operations such that none of the EETs would be exceeded, then the plan would not be required to include air quality modeling. This is because BOEM would already have determined that the potential effects resulting from the implementation of that plan would not have the potential to cause any such adverse effect. Under the proposed § 550.303(e), if none of a plan’s projected emissions or complex total emissions for any precursor or CP that exceeds the applicable emission exemption threshold, then its projected emissions would be considered de minimis, and therefore exempt, so that no further analysis would be required under subpart C. Under the proposed § 550.303(f), if a lessee’s or operator’s projected emissions or complex total emissions of the precursor or criteria air pollutant exceed the applicable emission exemption threshold, then further review would be required and potentially also controls. Under the proposed rule, the requirements associated with an exceedance would depend on which pollutant or pollutants exceed the threshold(s). If emissions of VOCs, which have no SILs, exceed a threshold, then controls would be required pursuant to proposed § 550.306 or 550.307, depending on whether the facility is short-term or long-term. If emissions of a criteria air pollutant exceed a threshold, then modeling would be required under proposed section 550.304. The current rule accounts for both of these two scenarios, just as the proposed rule would. The proposed rule would add provisions specifying circumstances in which additional photochemical modeling would be required. One of these proposed provisions would require photochemical modeling of O3 when projected emissions exceed the applicable emission exemption threshold for the O3 precursors NOX, VOCs, or CO. A second new proposed provision would require photochemical modeling for PM2.5 if a plan’s projected emissions of the PM2.5 precursors, NOX, VOCs, PM2.5, or SO2, exceed the applicable emission exemption threshold. In both cases, the proposed rule would not impose these photochemical modeling requirements, until such time as the conditions specified in § 550.304(b) have been met. PO 00000 Frm 00058 Fmt 4701 Sfmt 4702 Paragraph 550.303(g)—Changes to Previously Approved Plans The proposed rule would set requirements specifying when lessees and operators must submit revisions to their plans based on changes to how the plan will be implemented. The first proposed paragraph, (g)(1), would provide that, if a lessee or operator changes its plan implementation, such that its projected emissions would occur in years other than those that were previously approved, it would be required to submit a new plan and obtain approval before it implements the proposed changes. This requirement would relate to when operations occur, not the level of emissions associated with those operations. This proposed provision would formalize an existing practice whereby a lessee or operator is required to submit a new plan if the actual emissions associated with its operations will likely occur in years other than those proposed and approved in the original plan. Depending on the timing of the prospective emissions, the air impacts of those emissions would vary due to other activities in the area and to seasonal effects. For future years, the NAAQS or air quality benchmarks may change. In addition, the complex total emissions analysis may need to be redone or reevaluated. The second proposed paragraph, (g)(2), would provide that, if a lessee or operator anticipates any increase in the maximum air pollutant emissions above that projected for any time period described in the previously approved plan, the lessee or operator would be required to submit a new plan, pursuant to 30 CFR 550.283(a)(4). That existing section provides that an operator must submit a revised plan if it proposes to increase the emissions of an air pollutant to an amount that exceeds the amount specified in the approved plan. The proposed provision would relate to the peak emissions that would be generated by the facility, including its attributed emissions, for any time period (annual, 12-month rolling sum or maximum hourly) during its OCS operations. The third proposed paragraph, (g)(3), would provide that, if a lessee or operator proposes to make a change to operations on its existing facility or facilities, but not to the equipment used in such operations, such that its approved projected annual emissions in any given year are higher than those previously approved for the particular year, but lower than the maximum air pollutant emissions for any year, the lessee or operator would not need to E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules submit a revised plan—as long as the operations would occur in the same year as described in the previous plan. The fourth proposed paragraph, (g)(4), would require that a lessee or operator submit a new plan any time it proposes to change any equipment on its existing facility or facilities such that the proposed change would result in an increase in air pollutant emissions from that specific equipment for any air pollutant, regardless of the impact on the total emissions of the facility as a whole. The fifth proposed paragraph, (g)(5), would specify if a plan was approved for a short-term facility and it was determined later that the facility would be used in such a manner that it would properly be classified as a long-term facility, then a new plan must be submitted for review and approval by BOEM. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Paragraph 550.303(h)—Federal Land Manager BOEM currently consults with appropriate FLMs when it has reason to believe a lessee’s or operator’s proposed OCS activities could potentially cause a significant effect on air quality in a Class I area. Under the current practice, BOEM occasionally asks lessees and operators to submit additional information to show their proposed activities would not significantly affect the air quality of such areas. The proposed rule would expressly provide that BOEM may consult with one or more relevant FLMs if it believes emissions from proposed activities could potentially have a significant effect on Class I areas or sensitive Class II areas onshore or above State submerged lands. It would further provide that BOEM would consider the views of the FLMs in determining whether the proposed plan complies with the provisions of proposed subpart C. Based on this consultation, BOEM might require additional information and analysis, either prior to or as a condition of approving the plan. Finally, it would state that, if the FLM does not raise any concerns regarding the plan in a timely manner, BOEM would assume the FLM has no objections to the plan. Under current practice and the proposed rule, the FLMs would independently evaluate the potential impacts of air pollutant emissions from OCS activities because of their expertise, modeling and evaluation skills. They have the unique ability to evaluate and determine the likely impacts of OCS activities on Class I and sensitive Class II areas. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Section 550.304—What must I do if my projected emissions exceed an emission exemption threshold? Paragraph 550.304(a)—Dispersion Models Paragraph 550.304(a) of the proposed rule describes BOEM’s proposed dispersion modeling requirements, which would apply in the event the lessee or operator’s projected emissions or complex total emission exceed the limits defined in § 550.303(c). Dispersion modeling shows how a pollutant that is emitted could affect the concentrations of that pollutant onshore or above State submerged lands. BOEM has determined air pollutant emissions could potentially affect a State only under those circumstances where the total annual projected emissions or the complex total emissions of any given pollutant exceed a relevant exemption threshold. For this reason, a lessee or operator must perform modeling to estimate the projected increase in the ambient concentration of a pollutant onshore only if its proposed plan proposes projected emissions that exceed an emission exemption threshold for one or more criteria air pollutants. The proposed rule would clarify that if a lessee or operator’s projected emissions, or complex total emissions, of any given criteria or precursor pollutant exceeds an emission exemption threshold, then the lessee or operator would be required to model the potential impact of those emissions and those of any other pollutant for which the exceeding pollutant is a precursor, in order to determine the potential impact to the State. However, the rule would not require that a lessee or operator perform modeling with respect to those pollutants whose emissions are not projected to exceed any relevant EET. This approach is similar to that taken by the USEPA and is done for the same reason, namely to ensure that emissions are modeled in situations where a potential impact may occur. The USEPA method relies on the use of its SERs to make this determination, rather than requiring modeling, however.87 In addition, the proposed rule would make it explicit that modeling must be based on the projected emissions reported under 87 In USEPA’s case, any proposed facility that has been identified as a major source of emissions for any given pollutant must then be evaluated to determine whether that facility would generate emissions in excess of the Significant Emissions Rate (SER) for every other air pollutant. BOEM’s EETs are designed to accomplish a similar purpose, namely to identify situations where a proposed facility’s emissions may be potentially significant. PO 00000 Frm 00059 Fmt 4701 Sfmt 4702 19775 § 550.205(e), or the complex total emissions, whichever is applicable. This approach relies on the presumption that there would be one EET applicable at any given location for each precursor or CP. As an alternative, BOEM could establish multiple EETs for any given pollutant in those situations, such as for NOX, where the same pollutant is both a CP and a precursor for another CP. In this latter case, BOEM would not require modeling of any pollutant except in the case that that pollutant exceeded a relevant EET. The proposed rule would provide that a lessee or operator must use one or more of the following air dispersion models: An air dispersion model listed in appendix A to appendix W to 40 CFR part 51; an air dispersion model listed in the Federal Land Managers’ Air Quality Related Values Workgroup Guidance; or another model approved by the BOEM Chief Environmental Officer. The lessee or operator would also be required to follow the modeling procedures recommended in 40 CFR part 51 appendix W, as amended, to the extent possible. A lessee or operator would be required to provide BOEM with a copy of its dispersion modeling protocol and the associated data and assumptions used to do its analysis before it conducts such modeling. Paragraph 550.304(b)—Photochemical Models The proposed rule would require both dispersion and photochemical modeling, under a limited number of circumstances. For air photochemical modeling, the proposed paragraph (b) would also require lessees and operators use a model approved by the BOEM CEO and follow the modeling guideline provided in 40 CFR part 51 appendix W, as amended, to the extent possible. BOEM does not anticipate implementing a requirement for lessees and operators to conduct single source photochemical modeling for plan facilities until such time as it has determined that this modeling would be reasonable and practical for such lessees and operators, taking into consideration both the technical feasibility and the costs. The proposed rule in § 550.304(b) describes BOEM’s proposed photochemical modeling requirements.88 Photochemical 88 This section indicates that a photochemical model will be used under certain circumstances so long as it can be approved as an alternative model under Section 3.2 of Appendix W. This is similar to what the USEPA is proposing to do, in that the USEPA’s proposed revisions to Appendix W do not solely rely upon explicit use of photochemical E:\FR\FM\05APP2.SGM Continued 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19776 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules modeling shows the concentration increase onshore of an air pollutant that is formed as a result of photochemical processes in the atmosphere. Photochemical modeling would be required only if: (1) The projected emissions for the relevant precursor air pollutants exceed the applicable emission exemption threshold; (2) an appropriate photochemical air quality model is available that either meets the USEPA’s requirements in section 3.2 of 40 CFR part 51, appendix W, or complies with the FLM’s modeling guidance, or has been approved by BOEM’s CEO; and (3) BOEM has determined that adequate relevant information on background concentrations is available for the relevant location(s) in a potentially affected State. The proposed rule would require lessees and operators provide BOEM, upon request, with a copy of the photochemical modeling protocol and the associated data and assumptions used to perform the photochemical analysis before the actual modeling is conducted. The USEPA is currently evaluating the feasibility of establishing and requiring single source photochemical modeling, something that was technically challenging and generally cost prohibitive in the past. BOEM is reviewing the USEPA’s work in this area. Once BOEM has determined that the appropriate models are available, photochemical modeling may be done cost effectively, and the relevant background concentration data are available, BOEM will consider approving model(s) for use under this proposed section. Modeling protocols and the regional exemption studies supporting the EETs will likely allow BOEM to approve a photochemical model in the year 2020. In order to make a determination as to the appropriate circumstances under which single source photochemical models should be required, BOEM must also establish appropriate EETs as the screening mechanism. BOEM may develop EETs specific to O3 and PM2.5 formation, either in addition to or in lieu of specific SERs or EETs, or utilize reduced form photochemical models as a screening tool to determine the circumstances under which full single source photochemical modeling may be required.89 BOEM might consider models for each permit situation. Rather, EPA has a tiered approach with a first tier that uses existing information or reduced form models in lieu of full photochemical modeling. 89 BOEM is considering chemical transport models, including Lagrangian puff models and Eulerian grid (e.g., photochemical transport) models, as well. Lagrangian puff models would VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 current and future USEPA regulatory models, assessment techniques, and related guidance to develop EETs specific to O3 and PM2.5 formation. Paragraph 550.304(c)—Projected Emissions Section 550.304(c) of the proposed rule would require the lessee or operator to base its modeling on its maximum projected emissions, as reported under § 550.205(e), or on the complex total emissions in those situations where that reporting is otherwise required. Paragraph 550.304(d)—Meteorology Section 550.304(d) of the proposed rule would require, that for any modeling performed, lessees and operators must apply the best available and most recent meteorological dataset(s), either as directed in 40 CFR part 51 appendix W, or by using an alternate dataset(s) approved by the Regional Supervisor. In addition, the proposed rule would require lessees and operators to create a modeling report documenting all emissions sources, inputs, parameters, assumptions, procedures, methods, and results including input and output files, and data upon which their analyses under subpart C would be based, and to provide BOEM with copies of all data and access to any programs used in their modeling. Paragraph 550.304(e)—Estimates of Ambient Air Concentrations The proposed rule would specify in § 550.304(e) that, for each criteria air pollutant resulting from your projected emissions (or complex total emissions where applicable), the lessee and operator must estimate the peak incremental concentrations projected in any attainment area(s) and, separately, in any non-attainment area(s), in any State, including State submerged lands and onshore. BOEM is proposing this new requirement because the highest air pollutant concentration on the onshore area of a State may or may not occur at the onshore area that is closest to the require a realistic chemical environment for input, whereas photochemical transport models typically estimate a realistic chemical environment. Even though single source emissions are injected into a grid volume, comparisons with in-plume measurements indicate these types of models can capture downwind secondary pollutant impacts when applied appropriately for this purpose. Single source impacts estimated by photochemical grid models can be done by comparing a (1) model simulation with all sources and the project source at preconstruction levels and (2) model simulation with all sources and the project source at postconstruction levels. Alternatively, post-construction emissions could be tracked with photochemical grid model source apportionment or source sensitivity model extensions. PO 00000 Frm 00060 Fmt 4701 Sfmt 4702 facility described in the plan. Depending on the meteorology of the OCS region, the maximum concentration will likely occur at that point on the shoreline or above State submerged lands where the emissions are directed by the prevailing winds. The distinction between the peak attainment and peak non-attainment areas is important because the evaluation and ERM criteria are different for impacts to these two kinds of areas. Section 550.304(e) would require, to the extent practicable, estimates of the ambient air concentrations of any criteria air pollutant consider not only the dispersion of each criteria air pollutant itself, but also the formation of any criteria air pollutant that may result from the dispersion or presence of any relevant precursor air pollutant(s). The proposed rule would state specifically which precursors would be required to be included in the analysis of PM2.5 and O3. The proposed rule would also state that BOEM may provide information through Notices to Lessees to assist lessees and operators in evaluating existing ambient air concentrations, or changes in such concentrations over time, if BOEM determines that there is an effective means of estimating ambient air quality. Under the proposal, if BOEM has determined that there is an effective means of estimating ambient air quality and BOEM has established appropriate background concentration data for any given pollutant, at any given location and point in time, a lessee or operator would be required to use the relevant data provided by BOEM. Alternatively, in the event that BOEM has not determined appropriate background concentration data for any given pollutant, for any given location, and point in time, a lessee or operator would be required to use the relevant data from the USEPA for the closest appropriate location, as specified by the Regional Supervisor. Paragraph 550.304(f)—Attributed Emissions Section 550.304(f) would require that, for the purpose of calculating the relevant attributed emissions, lessees and operators conduct modeling of attributed emissions from those locations where those emissions are most likely to occur, utilizing the most appropriate line, area, volume, or pseudo point source model that would most accurately estimate the actual emissions that will result from MSCs, or other support operations. Under the current practice, in contrast, modeling is performed on the assumption that all E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules attributed emissions originate at the same location as that of a single stationary facility. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Paragraph 550.304(g)—Documentation and Reporting The proposed rule in § 550.304(g) would require the lessee or operator to create a modeling report documenting all emissions sources, inputs, parameters, assumptions, procedures, methods, and results, including input and output files, and underlying data upon which its analysis under this subpart is based. The rule would require the lessee or operator provide BOEM with copies of the modeling report, copies of all relevant data and the lessee or operator provide access to any programs used to perform their modeling. Section 550.305—How do I determine whether my projected emissions of criteria air pollutants require ERM? The proposed rule would require lessees and operators to compare the results of the modeling conducted under proposed § 550.304 with the USEPA’s Significant Impact Levels (SILs). If the modeling results are higher than the SILs, ERM would be required as specified in § 550.306, for a short-term facility, or as specified in § 550.307, for a long-term facility. Under current BOEM regulations, if modeling indicates an exceedance of the SILs, which the current regulations refer to as Significance Levels, this triggers the requirement to apply BACT. The table of Significance Levels in current § 550.303(e) was based on the table of the USEPA’s SILs as they existed in 1980. The USEPA’s tables, however, have been updated since then. The USEPA’s regulation on SILs, at 40 CFR 51.165(b), states that an emissions source ‘‘will be considered to cause or contribute to a violation of a national ambient air quality standard’’ when such a source would cause an exceedance of the SILs. Accordingly, BOEM is proposing to use the SILs to set the level of projected air pollution increase at a measurement point either onshore or above State submerged lands, that, if exceeded, ERM may be evaluated and controls may be required. BOEM is proposing to cross-reference the USEPA’s table of SILs so, if there is an update or addition that results in a change to the USEPA table, that change would automatically become incorporated into BOEM’s regulatory standards. Since PM2.5 is both emitted and formed in the atmosphere, lessees and operators would be required to add the results of their air dispersion modeling VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 for direct PM2.5 emissions to the results of their photochemical modeling, if required under proposed section 550.304, before comparing the results with the PM2.5 SILs. If the resulting sum exceeds a SIL for PM2.5 for any averaging time, the operator would be required to apply ERM. As set out in proposed section 550.304 and explained above, this additional modeling for PM2.5 would only be required if the relevant photochemical models and background concentration are available. In contrast to the other criteria air pollutants, the USEPA’s current regulations do not set a SIL or AAI for O3. Rather than determine equivalent standards for O3 at the present time, BOEM is proposing to require ERM based on emissions precursors of O3 when modeling would indicate the NAAQS for O3 would be exceeded. Accordingly, lessees and operators would be required to add the results of their photochemical modeling, if required under section 550.304, to the existing background concentrations and determine if a NAAQS for O3 would be exceeded for any averaging time. If any NAAQS is exceeded, the lessee or operator would be required to apply ERM. BOEM solicits comments both on this approach and whether photochemical modeling should be required in all cases. Alternatives could include reserving a full scale analysis until such time as the USEPA has established a SIL for O3, applying a consultative process between applicant and BOEM consistent with current appendix W until such time as revisions to appendix W have been finalized and the USEPA has established or recommended significance levels. Under the proposed rule, BOEM would eliminate the standard for TSPs, which measures the ambient concentration of particulates having a diameter of less than 100 micrometers. Instead, BOEM would formally adopt by cross-reference the two new standards that the USEPA created in place of the TSP standard: PM10 and PM2.5. PM10 represents an ambient air concentration standard for particulates of a diameter of 10 micrometers or less, while PM2.5 represents an ambient air concentration standard for particulates of a diameter of 2.5 micrometers or less. The USEPA’s annual and 24-hour averaging time SILs for PM10 are the same as those which BOEM currently applies to TSP.90 The current regulation’s reference to TSP 90 The annual SIL for TSP in the current BOEM regulations has an equivalent for PM10 because the USEPA has not revoked the annual SIL for PM10, although the USEPA revoked the annual NAAQS for annual PM10 subsequent to the publication of BOEM’s air quality regulations. PO 00000 Frm 00061 Fmt 4701 Sfmt 4702 19777 includes particulates of a larger size than those covered by the USEPA’s definition of PM10. At the time the current regulation was promulgated, the use of a TSP standard reflected the USEPA practice; however, the USEPA’s standard for PM10 has been in place since 1987. Because the USEPA standard has been in place for many years, the majority of OCS operators have already adopted this standard, and BOEM has largely replaced TSP with PM10 in the GOM. The existing SILs for other criteria air pollutants in BOEM’s current regulations would not change as a result of this revision in BOEM’s regulations, because they are currently set at the same levels as those set by the USEPA. The proposed rule would, however, incorporate the addition of new SILs established by the USEPA, since the adoption of BOEM’s original air quality rule. Going forward, there is the possibility that the USEPA will further change the SILs, or add new SILs, in which case BOEM’s decision to crossreference the USEPA’s regulation would automatically cause the BOEM significance threshold rates to change, as well. There are some circumstances where the USEPA has not established a SIL for a given CP or in which it has established only an interim SIL that it or the relevant State air quality regulatory authority may also use in evaluating the impacts of a proposed facility. In some circumstances, the USEPA may have established one or more SILs in its regulations and an additional interim SIL(s), typically for some other averaging time(s), outside of its regulations. In other cases, the USEPA may have repealed a SIL without establishing a new one. Thus, there may be situations where a lessee or operator may propose a plan that exceeds the relevant EETs, then perform modeling only to find there may not be a relevant SIL to compare against its incremental emissions or a situation where it may be unclear which SIL(s) to use. In similar situations where the USEPA or the State would issue an air quality permit, the USEPA or the relevant State permitting authority has issued permitting guidance to supplement its regulations. The proposed rule does not contain a provision on this topic and BOEM solicits comments on how best to address this issue. BOEM also requests comment on what BOEM should do about NAAQS that do not have corresponding SILs in the USEPA regulations; comments on the following two alternative approaches are particularly welcome. One alternative would be for BOEM to E:\FR\FM\05APP2.SGM 05APP2 19778 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS require in the final rule that, for any NAAQS (pollutant and averaging period) for which there is no SIL in 40 CFR 51.165(b)(2), lessee and operators must apply the appropriate SIL being used by the most affected State (at the point where the incremental emissions caused by the facility would be highest). Another alternative would be for BOEM to establish its own interim SILs based on the USEPA’s interim SILs, to be used unless and until the USEPA finalizes appropriate SILs in its regulation at 40 CFR 51.165(b). Section 550.306—What ERM are required for a short-term facility? Proposed § 550.306 would set forth the requirements for ERM for both criteria and major precursor pollutants on a short-term facility when modeling shows the facility will cause emissions to exceed the SILs, or when modeling will indicate a violation of the NAAQS for O3. ERM would also be required when emissions of VOCs exceed the EETs under the proposed § 550.303(b). Unlike the proposed requirements for a long-term facility, the proposed control requirements for a short-term facility would be the same for criteria and major precursor pollutants. Under BOEM’s existing regulations in § 550.303(h), ‘‘[t]he lessee shall apply BACT to reduce projected emissions of any air pollutant from a temporary facility which significantly affects the air quality of an onshore area of a State.’’ The current regulations also explicitly exempt temporary facilities from the requirements for controls set out in current regulations in § 550.303(g), which require additional analysis on top of the application of BACT for non-temporary facilities. In contrast, the proposed rule would require lessees and operators to apply only operational controls and/or equipment replacements, but not BACT in those situations where a SIL or VOC EET is exceeded. The proposed rule, like the current regulations, would not require additional AAI analysis after the application of ERM for a short-term facility. Under the proposed rule, an ERM analysis would start by identifying all available non-BACT control measures that would be relevant to the emissions of the pollutant(s) for which ERM would be required. The lessee or operator would then determine which of these are technically feasible. BOEM is proposing to define ‘‘technically feasible’’ in proposed § 550.302. The proposed rule would also add a requirement that a ‘‘demonstration of technical infeasibility must be clearly documented and must show, based on VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 physical, chemical or engineering principles, that technical difficulties would preclude the successful use of the applicable emission control technology or methodology.’’ The lessee or operator would rank the technically feasible control measures by their ability to reduce actual emissions, based on the overall emission control efficiency (e.g., percent pollutant removed, or emissions per unit of product) for each alternative. The lessee or operator would then evaluate and select the non-BACT ERMs that are technically feasible and that are designed to limit the facility’s projected emissions to the greatest practicable extent, taking into consideration the effectiveness of emissions control(s). Then the lessee or operator would be required to evaluate the cost effectiveness of each of the selected technically feasible operational controls in order to determine its economic impacts and feasibility. To justify elimination of an option on economic grounds, the lessee or operator should demonstrate that the costs of pollutant removal for that option are disproportionately high. As an alternative, lessees or operators could substitute permanent emissions credits for operational controls or equipment replacements, at their discretion. If no technically feasible operational controls or equipment replacements could be implemented cost effectively and the projected emissions affect only attainment areas, then no ERM would be required for the pollutant exceeding a standard other than those that the lessee or operator proposed in its plan. If no technically feasible operational controls or equipment replacements could be implemented cost effectively, and the projected emissions would affect a nonattainment area, then the Regional Supervisor could require the implementation of other ERM, including BACT, as a condition of approving the lessee’s or operator’s plan. Such ERM could be required on either a permanent or temporary basis, depending on the circumstances and location of the proposed facilities. If this ERM includes any proposed BACT, then the lessee or operator would be required to provide a description of the associated energy, environmental, and economic impacts, and other costs. The nature of any ERM could vary widely depending on the issue being addressed and the location of the relevant operations. Examples of such measures could be: Running specific equipment at optimal efficiency for certain periods of time, only operating certain equipment on specific days or for some number of days in a month or week or at specific times of day, etc. PO 00000 Frm 00062 Fmt 4701 Sfmt 4702 They could vary based on the existing background levels of pollution, the climatic conditions and the type of plan proposed. Operational controls could involve using specific types of fuel or specific types of combustion technology or limiting the use of certain equipment to a specific purpose or circumstance. They could also involve keeping certain equipment at a specified distance from other equipment or facilities, etc. The purpose of implementing such controls would be to keep the volume of air pollutants produced in connection with the operations conducted under a plan within a range such that none of the AAQSB would be violated, either on a temporary or ongoing basis, thereby ensuring such operations comply with BOEM air quality requirements. Paragraph (b) of the proposed section would specify what must be included in a lessee’s or operator’s plan describing the results of the ERM analysis. This would consist of: An evaluation of the ERM selected, quantifying and verifying the emissions reductions measures and associated costs; a description of how the selected operational controls or replacement equipment meets the criteria in § 550.309 for ERM; and a calculation of the revised projected emissions (or complex total emissions, where applicable), taking into account the selected operational controls or replacement of equipment. The proposed rule would specify that, if an operator has committed to apply appropriate operational controls or replacement of equipment, in the case of a plan affecting only an attainment area, or committed to apply appropriate ERM, with respect to a plan affecting a nonattainment area, BOEM could approve the plan, provided all other applicable requirements have been met. However, if BOEM were to have a reason to believe a lessee’s or operator’s projected emissions may cause the NAAQS to be exceeded, the Regional Supervisor could require additional data, analysis, or modeling to demonstrate compliance with the NAAQS or might require additional ERM so that the NAAQS are not exceeded. Section 550.307—What ERM are required for a long-term facility? Unlike short-term facilities, long-term facilities are generally intended to remain in operation for many years. Correspondingly, they, in conjunction with their MSCs, generally emit considerable amounts of air pollutants on an ongoing basis. Because of this, long-term facilities warrant more stringent air quality compliance requirements. This proposed section E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules describes the air quality control analysis required of such facilities. Proposed § 550.307 would set forth the requirements for ERM on a longterm facility when modeling shows the facility will cause emissions exceeding the AAIs or SILs (or when it would cause a violation of the NAAQS for O3). This proposed section would expand upon the existing control requirements for facilities in § 550.303(g) of the existing regulations. The current regulations mandate the application of BACT whenever a facility’s emissions exceed the SILs, but they then allow ‘‘the application of additional emission controls or through the acquisition of offshore or onshore offsets.’’ The proposed rule eliminates the preference for BACT and provides for additional options, including equipment swaps and operational controls. As is the case with current BOEM regulations, the requirements of this section differ depending on whether the potential impacts of any proposed facility would affect only attainment areas or whether non-attainment areas might also be affected. More stringent air quality requirements, of course, apply to situations where an area already exceeds a relevant pollution standard than in an area that is below that standard (i.e., has better overall air quality). BOEM has not proposed a definition of what ‘‘affect’’ means in this context but solicits comments on how this determination should be best made. One alternative would be that a facility that does not cause an exceedance of a SIL at any location in a State would not be considered to be one that impacts an affected area of the State. Conversely, any location at which a facility’s projected emissions could cause an exceedance of a SIL would constitute an affected area of a State for the purpose of this rule. The difficulty with this approach, however, lies in the fact that there may be many locations at which a SIL is exceeded and the boundary of this exceedance may be difficult or impractical to determine— particularly in the context of the nonattainment areas. Another alternative would be to require that any modeling be done with receptors just inside the outer boundary of a non-attainment area or at the attainment/non-attainment area boundary nearest to, or directly downwind of, the proposed facility. If modeling indicates that that no AAQSB would be exceeded at that point, then no non-attainment area would be considered affected by the proposed facility. There may be other approaches to handling the determination of affected VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 areas. BOEM would welcome suggestions or alternatives for how best to address this issue. Paragraph 550.307(a)—Control of Emissions of VOCs From a Long-Term Facility The proposed rule at § 550.307(a), like the current regulation, separates requirements for controls of VOCs from requirements for controls for other air pollutants. If the projected emissions of VOCs exceed an emission exemption threshold, then the lessee or operator would be required to apply controls. The controls required would depend upon the attainment status of the areas of the State(s) potentially affected by the emissions. If the projected emissions affect, or have the potential to affect, only attainment areas for O3 and PM2.5, then the lessee or operator would be required to propose ERM, excluding BACT, and would be required to demonstrate the proposed ERM would reduce the emissions of VOCs to the lowest practicable and reasonable rate (i.e., the lowest rate that can reasonably be achieved). If any designated nonattainment area for O3 or PM2.5 is affected, then the lessee or operator would be required to evaluate all the potentially applicable ERM, including BACT, and propose sufficient ERM to reduce VOC emissions below the applicable emission exemption threshold. For any proposed BACT, the operator or lessee would be required to provide a description of the associated energy, environmental, and economic impacts, and other costs. Paragraph (a)(3) of the proposed section would provide for an exception to the requirement to reduce VOC emissions when they affect a State coastal area where an increase in VOCs would not lead to the formation of increased O3 or would lead to a decrease in the formation of O3. The proposed rule would also provide that emissions credits could be utilized as an alternative to any other relevant ERM, regardless of the attainment or nonattainment status of any area that would potentially be affected by the projected emissions associated with any lessee or operator’s proposed plan. Paragraph 550.307(b)—Control of Emissions of Criteria Air Pollutants From a Long-Term Facility For emissions of criteria air pollutants, the controls that would be required for long-term facilities also depend on the attainment status of the area affected by the projected emissions. If all areas affected by the projected emissions are designated attainment areas, then the lessee or operator would PO 00000 Frm 00063 Fmt 4701 Sfmt 4702 19779 be required under § 550.307(b)(1) to evaluate all the potentially applicable ERM, excluding BACT, and propose sufficient ERM to reduce the ambient impact of the projected emissions and to conduct refined modeling to show the effects of the ERM, using the process described in proposed § 550.306(a)(1) through (4) for a short-term facility. Once the appropriate ERM have been determined, the lessee or operator should re-conduct modeling to evaluate the effect of applying ERM to reduce emissions and to determine whether or not the operator or lessee’s reduced emissions would cause an exceedance of the AAIs. Lessees and operators would be required to combine the ambient air effects of their emissions with the emissions from other onshore and offshore sources which contribute to the consumption of the maximum allowable increases above the baseline concentrations for each air pollutant and baseline area, as established in 40 CFR 52.21. In conducting this additional modeling, operators would be required to use the ambient air concentration data, as specified in proposed § 550.304(e)(2). If this modeling shows that ERM is not sufficient to reduce the projected concentration increases below the AAIs applicable to the potentially affected State, then the lessee or operator would be required to apply additional ERM and perform additional modeling until such efforts confirm that no AAIs would be exceeded. As discussed above, this was the intent expressed in the preamble to the BOEM’s current rule. This proposed rule would make this intent clear in the regulatory text itself. Once this additional modeling shows the ERM is sufficient to reduce the projected concentrations below the AAIs applicable to the potentially affected State, then the lessee or operator would be required to compare the resulting design concentration of each criteria air pollutant with the NAAQS. If any of the NAAQS are shown to be exceeded, the lessee or operator would be required to apply additional ERM and perform additional modeling until it determines none of the NAAQS would be violated. As discussed earlier, the current regulations use the MACIs in place of the AAIs for determining whether longterm facilities have sufficiently reduced their impacts on attainment areas. The MACIs were based on the AAIs at the time the current rule was promulgated. While BOEM is now proposing to crossreference the AAIs, it is also considering whether other standards would be better. Particularly, BOEM is considering whether it would be better E:\FR\FM\05APP2.SGM 05APP2 19780 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS to use standards that are based on a percentage of the level of the NAAQS, rather than the AAIs. BOEM would appreciate comment on this issue and on what standards to set. BOEM also requests comments on the most appropriate method for defining the size and extent of the relevant ‘‘baseline areas’’ for the purpose of conducting the AQRP analysis. Under the proposed rule at paragraph 550.307(b)(2), if projected emissions affect any area designated as a nonattainment area, then the lessee or operator would be required to evaluate all the potentially applicable ERM, including BACT, and propose sufficient ERM to reduce the ambient impact of its emissions of all criteria air pollutants below the applicable SILs at 40 CFR 51.165(b)(2). The proposed rule would then require a lessee or operator to conduct modeling using the revised projected emissions and compare the results with the SILs. If photochemical modeling would be required under § 550.304, then the lessee or operator would be required to also perform photochemical modeling and add the results of that modeling to the results of the additional dispersion models. If the modeling results exceed any SIL for any criteria air pollutant for any averaging time, then the lessee or operator would be required to apply additional ERM until additional modeling demonstrates all projected emissions have been fully reduced below the SILs for all criteria air pollutants for every applicable averaging time. Paragraph 550.307(c)—Exceptions to the ERM Requirement The proposed rule at § 550.307(c) would also provide that, for any averaging time other than an annual period, a facility’s projected emissions may cause an ambient impact that exceeds an applicable AAI one time during any rolling 12-month period for any given criteria air pollutant at any one location and still be considered to have fully reduced emissions. This provision is retained from the language in existing regulation § 550.303(g)(2)(i)(B), which states: ‘‘For any period other than the annual period, the applicable maximum allowable increase may be exceeded during one such period per year at any one onshore location;’’ however, slight changes have been made in the wording for clarity. Additionally, this proposed paragraph would provide that if an operator or lessee’s projected emissions of NOX potentially affect a State coastal area, but would not cause an increase, or would cause a reduction, in the formation of O3, then no ERM are VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 required for NOX. However, this exception would not apply if the potentially affected area is an attainment area for NO2 and the lessee or operator’s analysis indicates that the AAIs for NO2 would be exceeded in the absence of such ERM or if the potentially affected area is a nonattainment area for NO2. This proposed paragraph would also provide an exception if the implementation of a plan under these regulations would compromise the safety of the operation of the facility, and such implementation of any AAQSB cannot be otherwise addressed. Paragraph 550.307(d)—NAAQS Requirement Applicable to All Plans The proposed rule at § 550.307(d) would contain a provision, consistent with the current BOEM regulations at § 550.303(g)(2)(i)(B) (‘‘No concentration of an air pollutant shall exceed the concentration permitted under the national secondary ambient air quality standard or the concentration permitted under the national primary air quality standard, whichever concentration is lowest for the air pollutant for the period of exposure’’), stating no concentration of an air pollutant could exceed the concentration permitted under any primary or secondary NAAQS, whichever concentration is lowest for the air pollutant for the period of exposure. The proposed rule would state that NAAQS may not be exceeded, even for a short-term facility. Paragraph 550.307(e)—Emissions Credits The proposed rule would clarify that a lessee or operator may propose to use emissions credits to achieve the equivalent reduction of emissions for any criteria air pollutant as an alternative to any other ERM, regardless of the attainment status of the State area affected by its facility’s potential emissions. Section 550.308—Under what circumstances will BOEM require additional ERM on my proposed facility or facilities? The purpose of this proposed provision is to provide a safeguard to the plan approval process, such that any approval of a facility made according to these regulations does not cause a violation of an applicable air quality control standard. Because all of BOEM’s plan reviews are done on a prospective basis, it is possible the impacts of the implementation of such a plan could cause an adverse effect on a State that was not anticipated. This provision in the proposed rule provides a PO 00000 Frm 00064 Fmt 4701 Sfmt 4702 mechanism for State and local government entities, and certain Federally-recognized Indian tribes, that might be adversely affected by the approval of a plan or a RUE, pipeline ROW, or lease term pipeline application to raise objections on the basis of data or information that may not have been available to BOEM at the time a plan was originally approved. The current rule contains a similar provision that applies only to States. The current regulations, under § 550.303(j), provide ‘‘[i]f . . . the Regional Supervisor determines or an affected State submits information . . . which demonstrates . . . that projected emissions from an otherwise exempt facility will, either individually or in combination with other facilities in the area, significantly affect the air quality of an onshore area, then the Regional Supervisor shall require the lessee to submit additional information to determine whether emission control measures are necessary.’’ Paragraph 550.308(a)—Regional Supervisor Review The proposed rule at § 550.308(a) would expand upon this provision by specifying the Regional Supervisor could require the lessee or operator to apply additional ERM on either a temporary or permanent basis, depending on the circumstances, if he/ she determines the projected emissions, or, where applicable, complex total emissions, may cause or contribute to a violation of a NAAQS, based on (1) information submitted by a State, or a local government, or a Federallyrecognized Indian tribe; (2) information resulting from a cumulative impacts analysis conducted for a NEPA analysis; (3) a compliance review of a proposed plan under subpart B, § 550.232(b) for an EP, or § 550.267(c) for a DPP or DOCD; or (4) the declaration by an adjacent State, or the USEPA, of an air quality emergency for a location that may be affected by air emissions generated by operations. Paragraph 550.308(b)—Lessee’s or Operator’s Right To Challenge The proposed rule would provide in § 550.308(b) any lessee or operator affected by the requirements of this section would be given notice of the Regional Supervisor’s determination under paragraph (a) of this proposed section, as well as an opportunity to present additional information and analysis for review by the Regional Supervisor. Under the proposed rule, if the lessee or operator presents the Regional Supervisor with additional information and analysis, the Regional E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Supervisor would reassess whether the projected emissions, or complex total emissions, might cause or contribute to a violation of any NAAQS, and whether additional ERM would be required for the facility. Similar to the current regulations, under the proposed rule, the Regional Supervisor would then notify the affected State, or Federallyrecognized Indian tribe, and explain the reasons for this determination. Section 550.309—What requirements apply to my ERM? The proposed rule would provide explicit requirements to ensure the sufficiency, effectiveness, and control efficiency for a lessee’s or operator’s ERM. It also would specify how a lessee or operator could use emissions offsets. Paragraph 550.309(a)—Sufficiency Under the proposed rule at § 550.309(a), a lessee’s or operator’s proposed ERM would need to be sufficient to achieve actual emissions reductions corresponding to those reported in the plan for the duration of the plan’s operations under all reasonably foreseeable conditions. Under the proposed rule, the Regional Supervisor would review a lessee’s or operator’s proposed ERM on a case by case basis and make a determination whether such measures met the applicable criteria. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Paragraph 550.309(b)—Effectiveness Under § 550.309(b), the lessee or operator would need to continually ensure the effectiveness of its ERM for the duration of the plan’s operations under the proposed rule. If emissions reductions measures become disabled or unavailable, the lessee or operator must immediately notify the Regional Supervisor and replace such ERM with others of equal or superior effectiveness within 30 days of discovering the disability or unavailability, unless the Regional Supervisor approves an extension not to exceed 90 days. Paragraph 550.309(c)—Control Efficiency The proposed rule at § 550.309(c) would specify that the analysis of the proposed ERM would need to reflect actual ECE. The proposed rule would require a lessee or operator to substantiate any ECEs it projects and provide sufficient evidence to justify its projected ECEs to the satisfaction of the Regional Supervisor. The rule would further specify at § 550.309(c)(1) that, should the substantiating data indicate a range of efficiencies, the lessee or operator would be required to utilize the more conservative estimates (i.e., those VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 that would result in lower ECE) in its analysis and modeling. The intent of this provision is to ensure the proposed benefits that would result from BACT and/or other emissions controls would not be over-estimated, in order to ensure any controls that are proposed would be sufficient to actually reduce the emissions of a proposed facility to the levels projected in the analysis conducted pursuant to subpart C. Consistent with this, a further requirement is proposed at § 550.309(c)(2) whereby ECE estimates of 100 percent ECE would generally not be considered acceptable, except in cases where there is clear and convincing and/or historical evidence to justify their use. This requirement recognizes the fact there are virtually no emissions control mechanisms that can entirely eliminate all potential air pollutant emissions, and it is both unrealistic and unreasonable to make such an overstated estimate, without definitive evidence of its accuracy. Paragraph 550.309(d)—Emission Reduction Monitoring Further, under § 550.309(d), if ERM would be required in an approved plan, then the proposed rule would authorize the Regional Supervisor to require lessees and operators to provide information needed to verify the effectiveness and efficiency of the proposed ERM. The proposed rule states that a lessee or operator with a plan that is approved subject to the application of BACT must ensure that the emissions associated with each emissions source for which BACT is required complies with the emissions verification requirements of § 550.311 of this subpart. The rule further states that the Regional Supervisor may also require the installation of emissions measurement meters if the Regional Supervisor determines that such meters are necessary to ensure compliance with this requirement (i.e., that other alternatives may not be sufficient to ensure compliance). Paragraph 550.309(e)—Emissions Credits The purpose of acquiring an emissions credit is to cause a reduction in the emissions of a given pollutant from a business or activity unrelated to the plan, so that the total concentration of a given pollutant within a given area will not increase (as a result of the operations associated with a plan) beyond a permissible level. The proposed rule at § 550.309(d) would set forth requirements for emissions credits. First, the lessee or operator would be required to acquire PO 00000 Frm 00065 Fmt 4701 Sfmt 4702 19781 emissions offsets from emissions source(s), either offshore or onshore, that affect the air quality of the same AQCR). Second, for a CP, the emissions credits that the lessee or operator proposes would need to provide a net air quality benefit for the same pollutant; for a precursor pollutant, any emissions credits that a lessee or operator proposes would need to provide a net air quality benefit for that CP for which the pollutant is a precursor. Third, the lessee or operator would need to demonstrate to the Regional Supervisor that the emissions credit it proposes binds it and any other parties who agree to lower their emissions. Fourth, the lessee or operator would need to also demonstrate that any emissions reductions will last for the entire period of operations covered in its plan. The Regional Supervisor might periodically require the lessee or operator to certify that the emissions reductions are still in place. Fifth, any emissions credits would need to reduce emissions below rates otherwise required by law. Sixth, in addition to BOEM, the lessee or operator would be required to notify the appropriate State air quality control jurisdiction of its proposal to acquire emissions credits, modify the permit for the underlying onshore facility to reflect the proposed reduction in emissions and, if necessary, its need to revise the State Implementation Plan to include the information regarding the emissions credits the lessee or operator has acquired. Seventh, emissions credits would be allowed in those circumstances where BOEM could readily verify the historical emissions from the facility to be used for the emissions credit, and the emissions reduction associated with the acquired emissions credit. Eighth, the approval of an emissions credit would not be granted unless the reductions in emissions associated with the credit are verifiable by an appropriate State, tribe or federal agency (primarily through the modification of the air emissions permits for the relevant onshore facility). Finally, the proposed rule would specify that nothing in these regulations is intended to restrict emissions credits from being obtained and divided among multiple lessees or operators. If an OCS lessee or operator proposes to use emissions credits as an emission reduction measure (ERM), in lieu of BACT, operational controls or the replacement of equipment used on the OCS, then that lessee or operator would be responsible for ensuring that the reductions are permanent and verifiable. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19782 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules In the event that a lessee or operator elected to reduce the pollutant emissions of an onshore facility to offset corresponding emissions for a new facility proposed on the OCS, that lessee or operator could ensure that the reductions are permanent and verifiable by notifying the relevant State air quality regulatory body and seeking a modification of the permit for the underlying onshore facility to reflect the proposed reduction in emissions. The State could then update the permitted level of emissions which would ensure compliance with the reduced emissions requirements on an ongoing basis. The State could also update its SIP, if appropriate, and modify its reporting to the U.S. Environmental Protection Agency. BOEM does not believe that this process would be unduly burdensome to the States or that it would require any State-funded monitoring or compliance activities beyond those that are already in place or contemplated. Rather, BOEM believes that this process would largely be beneficial to the States, in that the reduction in air emissions of onshore facilities, beyond those that would otherwise be legally required, could cause a net air quality benefit to the States and localities affected. Such a change could also allow a greater level of economic development, and a greater number of approvals for additional stationary sources onshore than might otherwise be the case (in the absence of the emissions credit). For these reasons, BOEM believes that the potential use of emissions credits by lessees or operators would be neither onerous nor unreasonable. The proposed rule would allow emissions credits to be obtained and divided among multiple lessees or operators (presumably located near to one another in the vicinity of the State) in order to spread the costs of complying with air quality requirements over a broad area, or for any other reason. The manner in which the proposed rule would have the potential to affect the relationship between the federal and State governments has to do with a situation in which an OCS lessee or operator proposes to use emissions credits as an emission reduction measure (ERM), in lieu of BACT. In the event that a lessee or operator elected to reduce the pollutant emissions of an onshore facility to offset corresponding emissions for a new facility proposed on the OCS, that lessee or operator would be required to notify the relevant State air quality regulatory body and arrange for the modification of the permit for the VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 underlying onshore facility to reflect the proposed reduction in emissions. The State could then update the permitted level of emissions which would ensure compliance with the reduced emissions requirements on an ongoing basis. The State may also need to update its SIP, as appropriate, and modify its reporting to the USEPA. Lessees have not typically utilized emissions credits as a pollution mitigation measure in the past. BOEM solicits comments on the practicality and potential costs associated with the implementation of these proposals at the State level, as well as comments on how these proposals could most effectively be implemented in coordination with the States. Paragraph 550.309(f)—Emission Reduction Measures Under proposed § 550.309(f), unless otherwise specified, the lessee or operator could employ any operational control, equipment replacement(s), BACT, or emissions credit, on either a temporary or permanent basis, to reduce the amount of emissions that would occur in the absence of such measures. The proposed paragraph would also provide that any proposed ERM would become a condition of its plan upon approval and could be required on either a permanent or temporary basis, depending on the circumstances and location of the proposed facilities. In addition, the rule would clarify that any lessee or operator proposing a plan that includes equipment replacement would be subject to compliance with all other applicable federal regulations, including those of the USCG. Section 550.310—How will revisions to the ambient air standards or benchmarks affect my plan? Paragraph 550.310(a)—Review of Plans The proposed rule at § 550.310(a) specifies that BOEM would review air pollutant emissions data in a plan according to the AAQSB that are in effect on the date the plan is deemed submitted. Because BOEM’s regulations would cross-reference the USEPA’s standards, BOEM would make the appropriate changes to its review of plans if the USEPA revised such standards. Paragraph 550.310(b)—Proposed Plans The proposed rule at § 550.310(b) would specify that all activities described in initial, revised, modified, and supplemental plans would be required to comply with the AAQSB in effect on the date the plan is deemed submitted. PO 00000 Frm 00066 Fmt 4701 Sfmt 4702 The proposed rule, however, would provide exceptions in two situations. First, under § 550.310(b)(1), if a plan were deemed submitted shortly after the effective date of a new or revised AAQSB, and the lessee or operator believed the immediate application of the new or revised AAQSB would be impracticable or would otherwise impose an unreasonable hardship on its proposed operations, then the lessee or operator would be able to request a deferral from the requirement to comply with the new or revised standard. The Regional Director, with the concurrence of the Director, would review the request and would have the discretion to grant a temporary deferral, not to exceed two years, from compliance with the new or revised AAQSB based upon a finding of impracticability or undue hardship. Second, under § 550.310(b)(2), for any proposed plan, upon a finding that noncompliance with a new or revised AAQSB would not significantly affect the air quality of any State onshore or over State submerged lands, the Director would be able to grant a departure from compliance with the revised AAQSB. The Director would have the discretion to condition the departure upon any requirement(s) deemed necessary to avoid causing or contributing to a violation of the preexisting NAAQS. This exception would account for situations in which the USEPA could revise or add an ambient air quality standard or benchmark that would not be relevant to OCS operations or that would go beyond BOEM’s mandate to prevent significant effects on the air quality of a State, would be impracticable, or would otherwise impose an unreasonable hardship. Paragraph 550.310(c)—Approved Plans Under the proposed rule, if a lessee or operator is operating under an approved plan, it would be required to resubmit a plan for a periodic air quality review no more frequently than ten years after BOEM’s previous approval of the plan. This provision would be added in furtherance of the objective of section 5(a)(8) of OCSLA, which requires BOEM to ensure compliance with the NAAQS, and which makes no exceptions with respect to previously approved plans. All of the applicable requirements of this subpart in effect on the date of resubmission would apply on the same basis to a resubmitted plan as for an initial plan. BOEM requests comments on this provision, particularly with respect to the potential impact on lessees and operators. In order to ensure that the lessee or operator’s emissions remain compliant with OCSLA’s air quality mandate, E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules starting in 2020, subsequent to the date of the Notice, BOEM proposes to conduct periodic reviews of plans approved prior to the effective date of the new exemption thresholds. At that point, each lessee or operator whose plan was approved prior to the effective date of this proposed rule would be required to resubmit its plan for a new air quality review on a schedule listed in the proposed rule. Although the length of time required between the original plan review and the subsequent follow-up review would vary, in no case would a lessee or operator be required to re-submit its plan for an air quality review more than once every ten years.91 A plan initially submitted or resubmitted pursuant to this proposed provision would be required to comply with the provisions of § 550.205 as they exist at the time the plan is submitted, using the most current data on emissions factors and MSC emissions, and such a plan would, in all cases, be reevaluated against the EETs and formulas as they exist at the time of the plan resubmission, rather than those in effect at the time the plan was originally approved. When a plan is resubmitted under this provision that plan would be required to include estimates for the annual projected emissions for the subsequent ten years or for however long the facility would be expected to remain in operation, whichever is shorter. With respect to the emissions calculations for any given emissions source, the resubmitted plan would be required to account for the most recent available data on the actual emissions of that emission source. Under the proposal, if a plan would indicate an exceedance of any applicable emission exemption threshold, all applicable requirements of this subpart would apply as for an initial plan. For plans that were approved prior to the effective date of this rule, the lessee or operator would be required to submit a new plan for a new air quality review of its existing facilities according to a schedule in a table listed in the proposed rule. This table would require that the oldest plans be submitted first for re-review and that the most recently approved plans would be re-submitted last, according to the same ten-year review cycle. In each case, each plan would be due the same month as the month in which the plan was originally approved. 91 Unless the lessee or operator were required to re-submit a plan for reasons unrelated to the tenyear periodic review cycle (i.e., because it was proposing to change the plan schedule, add additional equipment or for some other reason). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 After the year 2023, plans would be re-reviewed every ten years; and the plan resubmission would be required in the month of the tenth anniversary of the initial plan approval, or the month of the tenth anniversary of the approval of a revised, modified, resubmitted or supplemental plan, whichever is later. If a lessee or operator proposes to make a change to the equipment on its existing facility or facilities in a year or years when its plan already anticipated operations, and its proposed change would result in an increase in air pollutant emissions from that equipment for any air pollutant, the lessee or operator would be required to submit a revised plan, not simply a plan that describes the specific change being proposed. The proposed rule would provide that if a lessee or operator fails to submit a revised plan as required under this section, then the previous approval of its plan would be revoked. In this circumstance the lessee or operator could also be subject to civil penalties or other appropriate sanctions, including the requirement to cease operations. Section 550.311—Under what circumstance will I be required to measure and report my actual emissions? The purpose of this section is to describe under what circumstances a lessee or operator would be required to demonstrate its actual emissions have been and are in compliance with its previously approved plan(s). Paragraph 311(a)—Compliance Demonstration Conditions Paragraph (a) of this proposed section would provide that facilities described in plans that were approved by BOEM under the listed conditions would be required to measure actual emissions: (1) If a plan is approved subject to the implementation of BACT or emissions credits; (2) if any emissions source on your facility uses any engine or equipment that is neither certified by the USEPA for domestic use in the U.S. nor MARPOL-compliant; (3) if the Regional Supervisor determines that lessees or operator’s projected emissions, complex total emissions, for any criteria or precursor air pollutant, calculated on either an annual basis or on the basis of a 12 month rolling sum, may significantly underestimate the actual emissions, based on either historical data or ambient air monitoring; or, (4) if BOEM determines that your facility is causing or contributing to an exceedance of the NAAQS in any State. PO 00000 Frm 00067 Fmt 4701 Sfmt 4702 19783 Paragraph 550.311(b)—Emissions Reporting Requirements For lessees and operators who would be required to measure and report actual emissions, proposed subsection (b) would state several basic requirements for measurement and reporting of actual emissions. Lessees and operators that are required to measure and report emissions would be required to include enough of the emissions sources to ensure that the actual emissions associated with facilities and MSCs operating under an approved plan are consistent with the projected emission limits approved for that plan. In other words, they would be required to demonstrate that a sufficient number of their large emissions sources are at or below the projected emissions for that equipment so that the emissions associated with the remaining emissions sources would not be sufficient to cause an exceedance of the projected emissions limits approved in the plan. Under the proposed rule, each lessee or operator would be required to consider every source that was included in its approved plan in addition to any source that would be classified as part of the projected emissions if the plan were resubmitted under the current regulations. Since the objective is to ensure that the actual emissions associated with facilities and MSCs operating under an approved plan do not significantly exceed the emissions projected for that plan, BOEM proposes to provide (as an option) a list of the kinds of emissions sources that lessees and operators could monitor to satisfy the requirements of this paragraph. On facilities, engine reporting and monitoring would include and apply to: Onboard facility engines; power generation engines; Hydraulic Power Units (HPU); deck cranes; cementing units; and other engines with a maximum power rating exceeding 200 hp (149 kW). On facilities, this list would exclude: propulsion engines, boilers and incinerators, emergency generators, and lifeboat engines. For MSCs, the emissions sources subject to measurement and reporting could include: Propulsion engines; power generation engines; marine auxiliary engines; and engines with a maximum power rating exceeding 200 hp (149 kW). On MSCs, this list would exclude boilers and incinerators, emergency generators, all engines onboard science vessels, offshore supply vessels, or lifeboats. Further, measurement of actual emissions would be required to reflect actual operations on the OCS and not exclusively on the basis of ECEs, fuel E:\FR\FM\05APP2.SGM 05APP2 19784 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules logs, or activity data. The lessee or operator would need to demonstrate that the data submitted to BOEM under this section is consistent with any data provided to BOEM under the requirements of § 550.187. The lessee or operator would be required to provide this information in a manner and on a schedule determined by the Regional Supervisor. BOEM solicits comments as to how it should best implement the requirements of this section with respect to those facilities that would be required to report their actual emissions. BOEM invites comments on this issue with respect to how best to achieve the objective of obtaining actual data on potentially large pollution emitters while not adversely impacting those small-volume emitters whose emissions do not have any realistic potential to adversely affect the air quality of any State. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Paragraph 550.311(c)—Notification Requirements Proposed paragraph (c) would require the lessee or operator to notify BOEM, if any of its actual emissions exceed its projected emissions at any time after the plan has been approved and to provide BOEM with the appropriate data regarding the exceedance. If a lessee or operator proposes to make a change to the equipment on its existing facility or facilities in a year or years when its plan already anticipated operations, and its proposed change would result in an increase in air pollutant emissions from that equipment for any air pollutant, the lessee or operator would be required to submit a revised plan, not simply a plan that describes the specific change being proposed. Paragraph 550.311(d)—Data Submittal Requirements As with the reporting done pursuant to § 550.205(d) of the proposed section would specify that a lessee or operator must submit data and information in a format, and using the forms, specified by BOEM. The lessee or operator must submit information in an electronicallyreadable format, unless otherwise directed by the Regional Supervisor. If it transmits the information to BOEM electronically, then it must use a delivery medium or transmission method authorized by BOEM. While the current regulation requires monitoring and reporting of emissions, it does not specify what monitoring is required. The proposed rule at § 550.311 would provide more specificity on how the monitoring and reporting must be carried out. BOEM believes a more VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 comprehensive approach to emissions measurement and monitoring could improve the quality and type of information for estimating impacts on affected States. BOEM requests comments and suggestions with respect to the best approach to post-approval record-keeping, monitoring and reporting, including potential alternative approaches. Section 550.312—What post-approval recordkeeping and reporting is required? Paragraph 550.312(a)—Stack Testing The proposed rule would include requirements necessary to validate the emissions estimates that are described in a plan. The proposed rule would specify at § 550.312(a) if stack testing was used as a method to develop emissions factors under proposed § 550.205 or was used to develop any other information submitted pursuant to that section, then a lessee or operator would be required to conduct the stack testing every three years and to report the results. BOEM seeks comment on whether it should require or recommend that the stack testing data be collected with the USEPA’s electronic reporting tool and submitted via CDX (Compliance and Emissions Data Reporting Interface-), so that the USEPA can update the AP 42/WebFIRE emissions factors and so BOEM can compile the relevant data and supply it to other lessees and operators for their use in the future. Paragraph 550.312(b)—Fuel Logs and Activity Data Proposed § 550.312(b) would describe the recordkeeping requirements that would be necessary to demonstrate compliance with the plan in all cases, whether or not ERM are required and whether or not the conditions in proposed § 550.311(a) were satisfied. Under the proposed rule, lessees or operators would be required to retain information on monthly fuel consumption, for each emissions source, including attributed emissions sources, showing the quantity, type, and sulphur content of fuel used; collect facility and equipment usage information, including hours of operation at each percent of capacity for each emissions source. Venting, flaring, flashing and any other release of any air pollutant emissions that would not otherwise be accounted for by fuel consumption would be required to be reported for any emissions source that generates criteria air pollutants or precursor air pollutants in connection with OCS activities. PO 00000 Frm 00068 Fmt 4701 Sfmt 4702 The proposed rule would require the lessee or operator to retain this information for a period of no less than 10 years. Reporting of fuel logs, facility and equipment activity and usage information, and fuel sulphur content must be provided to BOEM on a schedule established by the Regional Director. This provision is intended to ensure ongoing air quality compliance, after a plan is approved. It would both maintain consistency with the USEPA’s approach to regulating OCS operations and retain the requirements of BOEM’s current regulations at 30 CFR 550.303(k) and 550.304(g). If BOEM elects to obtain the relevant data for a lessee’s or operator’s attributed emissions from an independent third party, then the Regional Supervisor may waive the requirement to submit fuel logs or collect facility and equipment usage information for MSCs. BOEM solicits comment on whether there are other ways of collecting information or monitoring to ensure ongoing compliance with approved plans. Additionally, BOEM requests comment on alternative approaches to ensure compliance with an approved plan. BOEM also requests specific comment on whether there are ways to minimize the data collection and reporting burden associated with fuel logs while also ensuring the ongoing compliance with an approved plan. For example, there may be circumstances under which some facilities and/or MSCs would generate such low levels of emissions that there would be no practical possibility that the operations of those facilities and/or MSCs, cumulatively or separately, could exceed any relevant EET(s). Under those circumstances, the requirement to maintain fuel logs and/or activity data records may not be necessary or could be modified. BOEM solicits comment on what those circumstances may be and how BOEM might craft an exception or modification to the record-keeping requirements for small facilities and/or MSCs, so as to minimize the cost burden on lessees and operators—consistent with BOEM’s need to ensure the integrity of its air quality regulatory program. The proposed rule would also specify that record-keeping and reporting must be consistent with the USEPA’s requirements for Electronic Reporting and Recordkeeping Requirements for New Source Performance Standards. These are available in the following document: Electronic Reporting and Recordkeeping Requirements for New Source Performance Standards, 80 FR 15099, RIN 2060–AP63, March 20, 2015. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Paragraph 550.312(c)—Meteorological Reporting The current § 550.303(l) provides the Regional Supervisor may require, for a period of time and in a manner approved or prescribed, a lessee to collect and submit meteorological data from any of its facilities. The proposed rule in § 550.312(c) would include a provision with similar language. However, the proposed rule would add a provision allowing a lessee or operator to instead collect and report meteorological data derived from any other mutually agreed upon location with the approval of the Regional Supervisor. Paragraph 550.312(d)—Other Information The proposed rule in § 550.312(d) would add a provision to make clear the Regional Supervisor might require other information needed to support any finding or determination under subpart C. Paragraph 550.312(e)—Additional Requirements Imposed by Other Agencies The proposed rule would clarify that another federal agency could impose additional reporting, monitoring, or other requirements beyond those proposed by BOEM. None of the provisions of this paragraph would prevent the imposition of additional monitoring or reporting requirements on the part of BSEE or any other federal agency. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Section 550.313—Under what circumstances will BOEM impose additional requirements on facilities operating under already approved plans? The proposed rule would provide that under certain circumstances BOEM might impose additional requirements on existing facilities operating under approved plans. In addition to the new requirement that all plans be subject to a ten-year re-review process, the proposed rule would provide that BOEM might impose other requirements on facilities operating under an already approved plan if an applicable AAQSB changes or if BOEM determines the operations are: • Causing or contributing to a violation of the NAAQS, either individually or in combination with any other offshore operations (this provision would also account for plans approved with either a NOX or VOC waiver that may not continue to be appropriate); • Emitting unauthorized air pollutants; VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 • Creating conditions posing an unreasonable risk to public health or welfare; or • Violating any applicable federal, State or tribal law related to air quality. Also if a plan approved as a shortterm facility later becomes a long-term facility, the proposed rule would require a lessee or operator to submit an initial plan under the standards applicable to long-term facilities. The proposed rule would allow the Regional Director to grant a temporary exception to this requirement if the short-term facility became a long-term facility as a result of adverse weather conditions or other circumstances beyond the lessee’s or operator’s control that delayed operations in the lease area. The exception would not be allowed to exceed the number of months the lessee or operator had been unable to operate. Section 550.314—Under what circumstances will the Regional Supervisor review the projected emissions from my existing facility or facilities? The purpose of this proposed section is to outline the ongoing requirements, which are intended to ensure the lessee or operator will not allow its facility or facilities to generate emissions in excess of those approved in the plan. This section would update and modify the requirements in current § 550.304(a). That paragraph describes a process by which a State, or a Federallyrecognized Indian tribe having either a TAS status or a USEPA-approved TIP, can request more information about emissions data or the review of an existing plan. The proposed rule would provide that a State or Indian tribe could request that the Regional Supervisor to supply it with the air pollution data regarding an existing facility’s projected emissions, if such data were needed either for the updating of the State’s or Indian tribe’s emissions inventory or because a State or Indian tribe believed an existing facility’s projected emissions might cause or contribute to a violation of the NAAQS. The proposed rule would further provide that lessees or operators might be required to submit air pollutant emissions data to the entity submitting such a request. Further, under the proposed rule, the entity submitting a request would be permitted to submit information to BOEM that it believed indicated that projected emissions from an existing facility could cause or contribute to a violation of the NAAQS. In such a case, the lessee or operator responsible for the facility would be given the opportunity to present information to the Regional PO 00000 Frm 00069 Fmt 4701 Sfmt 4702 19785 Supervisor that demonstrates its facility’s projected emissions would not cause such an effect. The Regional Supervisor would evaluate the new information submitted and would determine whether the lessee or operator’s actual emissions, including their attributed emissions, would have the potential to cause or contribute to a violation of the NAAQS. The Regional Supervisor would base this determination on an evaluation of the emissions data, the available meteorological data, and the distance of the facility from the State or Reservation. If the Regional Supervisor were to determine an existing facility’s projected emissions had the potential to cause or contribute to a violation of the NAAQS, then the lessee or operator would be required to submit additional data as requested by the Regional Supervisor. This provision is intended to complement the provision described in § 550.205(m), which outlines those exceptional circumstances under which additional data or information may be required. D. 30 CFR Part 550, Subpart J The following change is proposed in part 550, subpart J: Section 550.1012—What are the air quality requirements for pipeline rightsof-way holders? Applications for rights-of-way are currently sent to and reviewed by BSEE. The proposed rule would not change that process except to add a requirement that any application for approval of a new pipeline ROW would also be subject to BOEM’s air quality requirements. The proposed rule would specify that when a person applies for a right-of-way (ROW) in any part of the OCS under the air quality regulatory jurisdiction of the Department, its application would be required to include the information required by § 550.205 of this part and demonstrate that the ROW complies with subpart C of this part. The proposed rule would also specify that any requirement in either § 550.205 or subpart C that refers to plans should be interpreted to apply equally to rights-of-way and that any requirement that refers to lessees should be interpreted to apply equally to ROW holders or grantees. There are a few exceptions proposed to these requirements that are based on the unique nature of pipeline ROWs: The provisions in subpart C that refer to the consolidation of multiple facilities and, the periodic resubmittal of plans under proposed § 550.310(c) would not apply to ROW holders or grantees. E:\FR\FM\05APP2.SGM 05APP2 19786 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules In addition, the proposed rule specifies that no additional requirements would apply to a proposed or existing RUE that is already included within the scope of an existing or proposed exploration or development plan. The proposed rule would also specify that BOEM will notify BSEE of its determination that the organization or individual has provided the information required by § 550.205 and met the requirements of subpart C of this part. If necessary, BOEM would notify BSEE of additional conditions necessary to ensure that the activities will comply with subpart C of this part. VI. Interagency and Public Outreach The Department has and continues to make a substantial effort to review its proposals with relevant stakeholders, both within and outside the federal government. It has conferred, and intends to continue to further confer, with the BSEE, the BLM, the FWS, the NPS, the USEPA, the United States Coast Guard (USCG), the National Oceanic and Atmospheric Administration and other relevant federal agencies prior to formulating the final rule. BOEM also intends to review this proposed rule with affected States. DOI strives to strengthen its government-to-government relationship with Federally-recognized Indian Tribes and Alaska Native Claims Settlement Act Corporations through a commitment to consultation with Indian Tribes and recognition of their right to selfgovernance and Tribal sovereignty. This proposed rule will be subject to an extensive public comment period and the views of all potentially affected industry and interested environmental groups will be solicited and carefully considered. The Department will consider and evaluate the comments of all potentially affected and interested parties, consistent with the OCSLA mandate that it appropriately balance the economic benefits associated with ‘‘expeditious and orderly development’’ against the potential environmental risks (i.e., ‘‘subject to environmental safeguards’’) that may be associated with any changes to existing air quality regulations. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS VII. Legal & Regulatory Analyses A. Statutes 1. National Environmental Policy Act (NEPA) of 1969 BOEM has developed a draft Environmental Assessment (EA) to determine whether this proposed rule would have a significant impact on the quality of the human environment under the NEPA. The draft EA is VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 available for review and public comment in the docket for this proposed rule at www.regulations.gov. Questions or comments related to the EA should be directed to Eric Wolvovsky at 45600 Woodland Road, Sterling, VA 20166; phone (703)787–1719; or email at Eric.Wolvovsky@boem.gov. 2. Paperwork Reduction Act (PRA) of 1995 This proposed rule contains a collection of information that has been submitted to the OMB for review and approval under 44 U.S.C. 3507(d). If you wish to comment on the IC aspects of this proposed rule, you may send your comments directly to OMB (see the ADDRESSES section of this notice). Please reference 30 CFR part 550, subpart C, Air Quality, 1010—NEW, in your comments. To see a copy of the IC request submitted to OMB, go to https:// www.reginfo.gov (select Information Collection Review, Currently under Review); or you may obtain a copy of the supporting statement for the new collection of information by contacting the Bureau’s Information Collection Clearance Officer at (703) 787–1025. The title of the collection for this rule is Air Quality, 30 CFR part 550, subparts A, B, and C (Proposed Rulemaking). This rulemaking proposes to add new IC requirements to current regulations under 30 CFR part 550, subparts A, B, and C. The IC for the current regulations has been approved under the following OMB Control Numbers: • 1010–0114 (subpart A), expires December 31, 2016 (30,635 hours; $165,492 non-hour costs). • 1010–0151 (subpart B), expires January 31, 2018 (432,512 hours; $3,939,435 nonhour costs). • 1010–0057 (subpart C), expires January 31, 2018 (112,111 hours; $0 non-hour costs). This rule would add new and expand existing requirements under regulations at 30 CFR part 550, subparts A and B, and would provide a rewrite of 30 CFR part 550, subpart C. Therefore, we are requesting OMB assign a new OMB Control Number for the IC requirements in the proposed rule. When the final rule becomes effective, we will move the requirements and burdens associated with subpart A and subpart B into their respective collections. We will use the new OMB Control Number for the IC requirements and burdens associated with the new subpart C and will discontinue the use of current OMB Control Number 1010–0057. The PRA provides 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. PO 00000 Frm 00070 Fmt 4701 Sfmt 4702 The rule proposes: To incorporate the USEPA’s regulatory standards for air quality; address the expansion of BOEM’s air quality jurisdiction to include the OCS adjacent to the North Slope Borough of the State of Alaska; account for technological advances in air quality measurement, evaluation, and reporting capabilities; take into account emissions from offshore supporting vessels; and reflect changes in practices and procedures as they have evolved. Potential respondents are holders and operators of federal OCS leases, operating rights holders, holders of Rights of Use and Easement (RUEs), holders of Pipeline Rights-of-Way (ROWs) or holders of a lease-term pipeline, and independent third-parties working on behalf of any of these persons. The frequency of response varies, but is primarily on the occasion or as per the requirement. Responses to this collection are mandatory or are required to obtain or retain a benefit. The IC does not include questions of a sensitive nature. BOEM will protect proprietary information according to the Freedom of Information Act (5 U.S.C. 552) and DOI’s implementing regulations (43 CFR part 2), 30 CFR part 552, OCS Oil and Gas Information Program, and 30 CFR 550.197, Data and information to be made available to the public or for limited inspection. We expect the estimated hour burden for the rulemaking to be 146,490 hours and $3,455,000 in non-hour costs. Some of the requirements, especially in subpart A, are not new; they are being moved or expanded. The table below provides a breakdown of the estimates for the rule. Current OMB-approved hours and requirements are in regular font; expanded requirements and hours are shown in italics. The proposed new requirements are shown in bold and are summarized as follows: • Subpart A. BOEM is proposing to implement a requirement from the CAA to work with the USEPA to expand and maintain a national air emissions inventory. The requirement to submit a copy of a USEPA-required Episode Avoidance Plan is currently approved as part of the IC in subpart C but would be collected under subpart A (§ 550.141(d)) in the proposed rule. We expect no burden change since the occurrence is very limited and therefore the burden currently approved is sufficient. The proposed rule would expand a requirement under right-of-use and easement (RUEs) to account for air quality documentation and records (§ 550.160( f ) +287 hours). The rulemaking also proposes to codify details regarding the gathering and reporting of OCS air inventory information, and broaden the requirement from being applicable only to the Western GOM to one that is applicable to all OCS regions. This requirement and the E:\FR\FM\05APP2.SGM 05APP2 19787 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules associated burdens are not new; they were originally accounted for in subpart C, but have been modified and moved to subpart A. The reasons for this are twofold. First, this requirement is unrelated to the regulatory requirements involving the review of the potential air quality impacts associated with proposed plans (i.e., the primary purpose of subpart C). Second, the requirements for collecting and maintaining air inventory information are meant to apply to all owners and operators of facilities, including lessees, lease operators, operating rights holders, holders of RUEs or pipeline ROWs—whether or not that ROW includes an accessory structure—and all owners and operators of non-stationary sources operating on the OCS in support of any facility, whether or not such person was required to submit or comply with the requirements of subpart C (New § 550.187, +112,425 hours). This would increase the total burden under subpart A +112,712 hours. • Subpart B. To simplify the air quality review process, BOEM is proposing to consolidate the requirements relating to air quality into one new section (§ 550.205), which would be equally applicable to all Exploration Plans (EPs), Development and Production Plan (DPPs), or DOCDs, as well as to any updates or modifications of any such plans. Proposed § 550.205 includes the expanded air quality emissions factors and reporting requirements for all emissions DOCDs +5,150 hours. The proposed rule also expands the current requirement to submit post-approval information for EP/DPP/DOCD to include RUEs (§ 550.284 +224 hours). This would increase the burden under subpart B +8,474 hours. • Subpart C. This rulemaking proposes a rewrite of current subpart C regulations to address new air pollution prevention and control requirements so we are addressing all requirements as new. This subpart would require analysis and modeling for expanded air emissions and compliance reporting for those criteria and major precursor air pollutants that exceed the threshold, and allow for air emissions consolidation from multiple facilities (expanded from current regulations) (§§ 550.303 and 550.304; 6,626 hours, $1,000,000 non-hour costs for modeling). This subpart would also add the requirements associated with emission reduction measures, including but not limited to the BACT (§§ 550.306 through 550.310; 682 hours), as well as monitoring and reporting requirements, including the collection of data and maintenance of fuel logs (§§ 550.311 through 550.314; 17,986 hours, $2,455,000 non-hour costs); and general departure information (§§ 550.300 through 550.314; 10 hours). The proposed rule would create new subpart C with a total burden of 25,304 hours and $3,455,000 nonhour costs. sources. The proposed rule would expand BOEM’s air quality submission requirements to include any area in which BOEM is given jurisdiction, including the OCS adjacent to the North Slope Borough of the State of Alaska. To accommodate various changes in the air quality requirements, BOEM will modify its current air quality information forms (BOEM–0138, Air Emission Calculations for EPs, and BOEM–0139, Air Emission Calculations for DPPs and DOCDs). These forms will be updated to include the new air pollution emissions factors and to reflect the addition of new emissions sources and categories and types of equipment and vessels (e.g., icebreakers). The forms will be restructured to better accommodate the consolidation of emissions across multiple, related facilities; to better reflect the goal of complying with USEPA AAQSB; and to reflect various other changes necessitated by the proposed rulemaking. The forms will be renamed so that it is clear that they are intended to be applicable and functional for all affected OCS Regions. BOEM is working with a contractor to revise these forms to provide automated calculations after data entry. The draft forms will be included in the docket for this proposed rulemaking and will be made available for public comment. The proposed modifications to the forms will increase the current aggregated burdens for submitting an EP, DOCD, and DPP by the following: for EPs, +3,100 hours; for DPP/ BURDEN TABLE [Current requirements in regular font; expanded requirements shown in italic font; new requirements shown in bold font] Citation 30 CFR part 550 subpart A and related NTLs Reporting and recordkeeping requirement ** Average number of annual responses Hour burden Annual burden hours Per the requirements in this rule, you must submit information in an electronically readable format unless otherwise directed by BOEM. If you transmit the information electronically, you must use a delivery medium or transmission method authorized by BOEM Information and Reporting Requirements 141(d) ................................ Request approval to use new or alternative procedures; temporarily suspend equipment or implement operational control(s); submit required information. 160(f) ................................. Submit all air quality documentation/records pertaining to RUE applications; obtain approvals. Request waiver of 10-year periodic review for RUEs from Regional Supervisor. Entities in all affected OCS Regions collect, maintain, retain for 10 yrs., and all air emissions-related data for each source that generates air pollutants on the OCS. Request third-party submission of required air emissions data to BOEM or BOEM-designated agent. 160(f) ................................. New 187* .......................... New 187(b)* ...................... asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Total for Subpart A .. Burdens currently covered under 30 CFR part 550, subpart A (1010–0114) 0 11 26 applications ................. 286 .50 2 ....................................... 1 43+ 2,547 submissions ......... 112,025 2 200 requests ................... 400 .................................................................................... ........................ 2,775 ................................ 112,712 Reporting and recordkeeping requirement Hour burden Average number of annual responses Citation 30 CFR 550 subpart B and related NTL(s) Annual burden hours Contents of Exploration Plans 200–206; 209; 215(e); 231(b); 232(d); 234; 235; 281(d)(3); 283; 284; 285; NTL 2010 N–06. VerDate Sep<11>2014 Submit amended, modified, revised, supplemental, or updated EP, or resubmit disapproved EP; withdraw an EP. 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00071 Fmt 4701 Sfmt 4702 Burdens currently covered under 30 CFR 550, subpart B (1010–0151) E:\FR\FM\05APP2.SGM 05APP2 0 19788 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Citation 30 CFR 550 subpart B and related NTL(s) Reporting and recordkeeping requirement New 205 ............................ Collect, maintain & submit all air quality & modeling documentation/records (including but not limited to, emissions sources, factors, reduction measures, attributed and projected emissions, distance calculations, etc.); additional documentation as requested/required by BOEM; request departures; obtain approvals. 200–206; 209; 211 through 228; NTL 2010–N–06. Submit EP and all required information (including, but not limited to, submissions required by BOEM forms 0137, 0138, 0142; withdrawals; lease stipulations; reports; H2S; Geological and Geophysical (G&G); etc.); provide notifications. New 205 ............................ Submit expanded air emissions & compliance data for EPs whose air emissions are above the exemption threshold. Burdens for analysis/modeling covered under 30 CFR part 550, subpart C (§§ 550.303–550.307). Collect, maintain & submit all air quality & modeling documentation/records (including but not limited to, emissions sources, factors, reduction measures, attributed and projected emissions, distance calculations, etc.); additional documentation as requested/required by BOEM; request departures; obtain approvals. Alaska Region submits air quality information as required in EP. Subtotal ..................... Average number of annual responses Hour burden .................................................................................... 20 110 changed plans ........ Burdens currently covered under 30 CFR part 550, subpart B (1010–0151) Annual burden hours 2,200 0 25 20 plans .......................... 500 200 2 Alaska plans ............... 400 ........................ 132 ................................... 3,100 Contents of DPP and DOCD Submit amended, modified, revised, updated, or supplemental DPP or DOCD, or resubmit disapproved DPP or DOCD. New 205 ............................ Collect, maintain & submit all air quality & modeling documentation/records (including but not limited to, emissions sources, factors, reduction measures, attributed and projected emissions, distance calculations, etc.); additional documentation as requested/required by BOEM; request departures; obtain approvals. 200–206; 209; 241 thru 262; NTL 2010 N–06, and others. Submit DPP/DOCD and accompanying/supporting information (including, but not limited to, submissions required by BOEM Forms 0137, 0139, 0142 used in GOM; lease stipulations; withdrawals, etc.); provide notifications. New 205 ............................ asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Current 200–206; 209; 266(b); 267(d); 272(a); 273; 281(d); 283(a–b); 284; 285(a–b); NTL 2010 N–06. Submit expanded air emissions & compliance data for DPPs/DOCDs whose air emissions are above the exemption threshold. Burdens for analysis/ modeling covered under 30 CFR part 550, subpart C (§§ 550.303–550.307). Collect, maintain & submit all air quality & modeling documentation/records (including but not limited to, emissions sources, factors, reduction measures, attributed and projected emissions, distance calculations, etc.); additional documentation as requested/required by BOEM; request departures; obtain approvals. Alaska Region submits air quality information as required in DPP/DOCD. Submit updated information on activities conducted under approved EPP/DPP/DOCD/RUE. 284 .................................... Subtotal ..................... VerDate Sep<11>2014 .................................................................................... 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00072 Fmt 4701 Sfmt 4702 Burdens currently covered under 30 CFR part 550, subpart B (1010–0151) 20 155 changed plans ........ Burdens currently covered under 30 CFR part 550, subpart B (1010–0151). 0 3,100 0 25 50 plans .......................... 1,250 400 2 Alaska plans ............... 800 4 56 updates ....................... 224 ........................ 263 ................................... 5,374 E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Citation 30 CFR 550 subpart B and related NTL(s) Total Subpart B Reporting and recordkeeping requirement Hour burden Average number of annual responses .................................................................................... ........................ 19789 Annual burden hours 395 ................................... 8,474 Non-hour costs Citation 30 CFR 550 subpart C and related NTL(s) Reporting and recordkeeping requirement Average number of annual responses Hour burden Annual burden hours Air Quality Analyses in Plans New 303–307 .................... Conduct required analysis & modeling for expanded air emissions for those criteria & major precursor air pollutants that exceed the threshold & compliance requirements. Submit modeling reports. 38 87 plans .......................... 3,306 $10,000 × 20 instances for incremental modeling/analysis cost of mobile sources = $200,000 $20,000 × 40 instances for additional plans that will now require modeling/analysis = $800,000 $50,000 × 0 instances for plans now requiring photochemical modeling/analysis = no costs till 2020 $1,000,000 New 303(d) ....................... Report/consolidate air emissions data from multiple facilities if required. 20 15 consolidations .......... New 303(g); 310(c); 312(b) Submit revised air emissions plans, as required. Request exceptions; obtain approvals. New 303(h) ....................... 10 300 submissions ............ 3,000 New 304 ............................ Provide additional information/analysis as required for plan approval. Obtain approval of all modeling protocols & meteorological data sets. Provide BOEM with copies of/access to protocols & all required information. 5 4 submissions ................ 20 Subtotal ..................... .................................................................................... ........................ 406 ................................... 6,626 Burdens currently covered under 30 CFR part 550, subpart B (1010–0151). 300 0 $1,000,000 Non-hour Costs Emission Reduction Measures—BACT New 306; 307; 308(a); 309(a), (c), (d). New 307(a); 313(a) ........... Document results of ERM analysis. Provide description of BACT proposal/data based on required analyses, associated impacts and costs; demonstrating compliance; provide additional information as required; obtain approval; Submit ECE data from manufacture. Request VOCs or NOX waiver for ERM .................... New 308(b); 309(a) ........... Request reconsideration of BOEM emissions determination; submit supporting information. New 309(b) ....................... Immediately notify BOEM if ERM become disabled or unavailable; request extension for ERM (NTE 90 days). Collect and maintain monthly logs of relevant meter/ monitoring equipment readings. Notify appropriate State air quality control jurisdiction of proposal to acquire emissions offsets; revise State Implementation Plan to include new info; submit to BOEM. Request a departure from compliance with the new or revised AAQSB. New 309(d) ....................... asabaliauskas on DSK3SPTVN1PROD with PROPOSALS New 309(e) ....................... New 310(b) ....................... New 310(c) ....................... Resubmit plans for air quality review every 10 years w/required information. Subtotal ..................... .................................................................................... VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00073 Fmt 4701 Sfmt 4702 50 12 submissions .............. 600 1 1 ....................................... 1 Not considered IC as defined in 5 CFR 1320.4(a)(2). 0 2 2 notifications ................ 4 12/yr. 6 ....................................... 72 1 1 notification .................. 1 2 2 requests ....................... 4 There will be no burden until 2020 ........................ 24 ..................................... E:\FR\FM\05APP2.SGM 05APP2 0 682 19790 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Non-hour costs Citation 30 CFR 550 subpart C and related NTL(s) Reporting and recordkeeping requirement Average number of annual responses Hour burden Annual burden hours Monitoring & Reporting New 311(a), (b), (f) ........... New 311(c) ....................... Report/demonstrate actual emissions data/other information to verify compliance with previous approved plan on BOEM approved schedule. Measure actual emissions using Predictive Emission Monitoring System (PEMS). 16 12 submissions .............. 192 36 30 engines ...................... 1,080 $26,000 μ 30 engines = 780,000 annually New 311(c) ....................... New 312(b), (d); ................ New 312(a) ....................... Report data/information regarding exceedance of projected emissions to BOEM. Submit additional information as required to BOEM Conduct/report stack testing results every 3 yrs ....... 16 5 ....................................... 80 2 48 10 submissions .............. 67 tests ........................... 20 3,216 $25,000 μ 67 stack tests = $1,675,000 annually New 312(b) ....................... New 312(b) ....................... New 312(c), (d) ................. New 313(b) ....................... New 313(b) ....................... New 314 ............................ Retain monthly fuel information for each source on determined schedule for 10 yrs. Submit fuel logs or collect facility and equipment usage information for MSCs to BOEM. Collect/report meteorological data in a manner described by BOEM or from agreed location; other information as required. Submit new air quality plan for short-term facility converted to a long-term facility. Request exception due to adverse weather conditions or circumstances beyond your control. Provide pollution data to State, Indian Tribe, or federal agency requests submit additional info. for determination to any cause/contribution to NAAQS violation within 120 days or a longer time specified by BOEM. 48 265 ................................... 12,720 8 80 ..................................... 640 4 3 ....................................... 12 10 2 submissions ................ 20 .50 4 ....................................... 2 2 2 requests ....................... 4 480 ................................... 17,986 Subtotal ..................... .................................................................................... ........................ $2,455,000 Non-hour Costs General New 300–314 .................... General departure and alternative compliance/requests not specifically covered elsewhere in subpart C. 2 5 requests ....................... 10 Subtotal ..................... .................................................................................... ........................ 5 ....................................... 10 Total for Subpart C. .................................................................................... ........................ 915 ................................... 25,304 $3,455,000 Non-Hour Costs Reporting and recordkeeping requirement 1012 .................................. Collect, maintain & submit all air quality documentation/records pertaining to pipeline ROW applications; obtain approvals.. Total Burden ............. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Citation 30 CFR 550 subpart J and related .................................................................................... Average number of annual responses Hour burden Annual burden hours Burden covered under 30 CFR part 550, subparts B and C. ........................ 4,085 ................................ 0 146,490 $3,455,000 Non-Hour Costs * The requirements and burdens added to 30 CFR part 550, subpart A, are not entirely new; they are in current 30 CFR part 550, subpart C. This rulemaking moves those requirements to subpart A. ** In the future, BOEM will be allowing the option of electronic reporting for certain requirements. + Exact numbers of responses and annual burden hours were approved by OMB January 2015; numbers are from ROCIS. BOEM uses the information collected under subparts A, B, and C to ensure operations on the OCS are carried out in VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 a safe and environmentally sound manner, do not interfere with the rights of other users, and balance the PO 00000 Frm 00074 Fmt 4701 Sfmt 4702 protection and development of OCS resources. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules As part of our continuing effort to reduce paperwork and respondent burdens, we invite the public and other federal agencies to comment on any aspect of the reporting and recordkeeping burden. We specifically solicit comments on the following questions: (1) Is the proposed collection of information necessary for BOEM to properly perform its functions, and will it be useful? (2) Are the estimates of the burden hours of the proposed collection reasonable? (3) Do you have any suggestions that would enhance the quality, clarity, or usefulness of the information to be collected? (4) Is there a way to minimize the IC burden on those who must respond, including the use of appropriate automated electronic, mechanical, or other forms of information technology? In addition, the PRA requires agencies to estimate the total annual reporting and recordkeeping non-hour cost burden resulting from the collection of information, and we solicit your comments on this item. For reporting and recordkeeping only, your response should split the cost estimate into two components: (1) Total capital and startup cost component; and, (2) annual operation, maintenance, and purchase of services component. Your estimates should consider the costs to generate, maintain, and disclose or provide the information. You should describe the methods you use to estimate major cost factors, including system and technology acquisition, expected useful life of capital equipment, discount rate(s), and the period over which you incur costs. Generally, your estimates should not include equipment or services purchased (1) before October 1, 1995; (2) to comply with requirements not associated with the IC; (3) for reasons other than to provide information or keep records for the Government; or (4) as part of customary and usual business or private practices. OMB is required to make a decision concerning the collection of information contained in these proposed regulations between 30 to 60 days after publication of this document in the Federal Register. Therefore, a comment to OMB is best assured of having its full effect if OMB receives it by May 5, 2016. This does not affect the deadline for the public to comment to BOEM on the proposed regulations. If you wish to comment on the IC aspects of this proposed rule, you may send your comments by email directly to OMB (OIRA_submission@omb.eop.gov) or by VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 fax 202–395–5806, with a copy to BOEM (see the ADDRESSES section). Please reference Air Quality, 30 CFR part 550, subparts A, B, and C (Proposed Rulemaking) in your comments. To see a copy of the IC request, with the draft proposed forms, submitted to OMB, go to https://www.reginfo.gov (select Information Collection Review, Currently under Review). You may also obtain a copy of the supporting statement and draft forms for the new collection of information by contacting Nicole Mason, the Bureau’s Information Collection Clearance Officer, by mail at 45600 Woodland Rd., Sterling, VA 20166, by email at Nicole.Mason@ boem.gov, or by phone at (703) 787– 1025. 3. Regulatory Flexibility Act and Small Business Regulatory Enforcement Fairness Act of 1996 The Regulatory Flexibility Act, 5 U.S.C. 601–612, requires agencies to analyze the economic impact of proposed regulations when a significant economic impact on a substantial number of small entities is likely and to consider regulatory alternatives that will achieve the agency’s goals while minimizing the burden on small entities. In addition, the Small Business Regulatory Enforcement Fairness Act of 1996, 5 U.S.C. 601 note, requires agencies to produce compliance guidance for small entities if the rule has a significant economic impact. For the reasons explained in this section, BOEM has concluded that the proposed rule would likely not have a significant economic impact on a substantial number of small entities and, therefore, a regulatory flexibility analysis is not required. This Initial Regulatory Flexibility Analysis (IRFA) assesses the impact of the proposed rule on small entities, as defined by the applicable Small Business Administration (SBA) size standards. The IRFA can be found in the Initial Regulatory Impact Analysis (IRIA) within the docket for this rulemaking. The IRFA assesses the impact of the proposed rule on small entities, as defined by the applicable SBA size standards. Based on this initial analysis, BOEM expects the implementation of this proposed rule may have a significant economic impact on a substantial number of small entities under 5 U.S.C. 605(b). BOEM, however, is seeking comments on the IRIA to inform its analysis and conclusions regarding the degree to which this rule may have an economic impact on such entities. As defined by the SBA, a small entity is one that is ‘‘independently owned and operated and which is not PO 00000 Frm 00075 Fmt 4701 Sfmt 4702 19791 dominant in its field of operation.’’ The definition of small business varies from industry to industry in order to properly reflect industry size differences. The proposed rule would affect operators and holders of BOEM-issued oil and gas leases that are seeking to explore, develop or transport OCS oil and gas resources. BOEM’s analysis shows that this could include about 130 companies with active operations. Entities that operate under this rule fall under the SBA’’s North American Industry Classification System codes 211111 (Crude Petroleum and Natural Gas Extraction) and 213111 (Drilling Oil and Gas Wells) or 237120 (Oil and Gas Pipeline and Related Structures). For these codes, a small company is defined as one with fewer than 500 employees. A small entity is one that is ‘‘independently owned and operated and which is not dominant in its field of operation.’’ Based on this criterion, approximately 90 (69 percent) of the 130 companies operating on the OCS are considered small and the remaining are considered large businesses. Of the approximately 130 operators, a total of 56 companies submitted initial, revised, or supplemental exploration/ development plans during calendar year 2013. Twenty-four large companies submitted 63 percent of the plans and thirty-two small companies submitted 37 percent of the plans. Operators not submitting exploration or development plans typically are continuing existing operations or hold leases undergoing geological and geophysical exploration. Submitting an exploration or development plan is a necessary step before companies explore for hydrocarbons on the OCS or develop an economic prospect. All companies operating on the OCS including small entities must be well capitalized to undertake these multi-million or multibillion dollar projects. The incremental cost for providing additional or consolidated air quality information for exploration plans, DOCDs or DPPs, ROWs or RUEs is a small cost in the context of an exploration or development project. Most of the compliance costs imposed as a result of this rulemaking are variable costs directly dependent on the complexity and number of plans submitted. Emission reduction measure costs would be directly related to the impact a project may have on a State’s air quality. BOEM’s first-order estimate for the rulemaking’s small entity compliance costs is proportional to the number of plans submitted excluding ERM costs. The compliance costs from this rulemaking may be less for most small E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19792 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules entities because these companies are less likely to operate the large projects that employ multiple MODUs drilling concurrently. If a facility or project is located close to the federal/State submerged lands boundary, shows emissions above the SILs in a nonattainment area and is operated or owned by a small entity, this proposed rule could have an economic impact. The GOM shelf is a mature hydrocarbon environment and few companies are initiating new exploration or development projects. However, the GOM shelf is where most of the small entities operate and hold leases. While most of the compliance costs would be imposed on lessees and operators of large deepwater projects, some nearshore projects may be impacted. Using 2013 as a base, small companies submit about 37 percent of the plans each year and are expected to incur approximately the same proportion of costs. The incremental first year compliance costs for this rulemaking are projected to be $23 million and the peak year is $49 million. Some of those costs are for ERM or emissions credits on a very small number of projects which may or may not be owned or operated by small entities. The modeling, reporting and other costs range from $7 to $28 million each year and small entities operating in the GOM are estimated to incur a similar proportion (37 percent) of costs in each subsequent year. As described in more detail in the Executive Summary to the Regulatory Impact Analysis (RIA), these costs are expected to vary from approximately $3 million in the first year up to $10 million in the 10th year. BOEM prepared an IRFA to assess the impact of the proposed rule on small entities, as defined by the applicable SBA size standards. The IRFA is prepared using conservative assumptions and seeks public comments on potential small entity impacts. This rule would only affect operators and federal oil and gas lessees that could conduct operations on the OCS. The Regulatory Flexibility Act, 5 U.S.C. 601–612, defines small entities as small businesses, small nonprofits, and small governmental jurisdictions. We have identified no small nonprofits or small governmental jurisdictions that the rule would impact. For the reasons explained below, BOEM has concluded this rule will not have a significant economic impact on a substantial number of small entities and that, therefore, a regulatory flexibility analysis is not required. This incremental modeling and reporting costs for this rulemaking will VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 generally be required of both the larger deepwater projects and near-shore projects. While there are smaller companies that explore and operate in deeper water, these companies are well capitalized and the incremental compliance costs for this rulemaking are estimated to be minimal when compared to the cost of drilling a single deepwater well. Although BOEM does not believe that the proposed rule would have a significant economic impact on a substantial number of small entities, BOEM is requesting comment on the costs and impacts of the proposed policies in this rule on small entities. We will consider all comments at the final rule stage. We specifically request comments on the compliance cost estimates as well as regulatory alternatives that would reduce the burden on small entities. This proposed rule: a. Would not have an annual effect on the economy of $100 million or more. The compliance cost will not materially affect the economy nationally or in any local area. b. Would not cause a major increase in costs or prices for consumers; individual industries; federal, State, tribal or local government agencies; or geographic regions. This proposed rule would have minimal effects on OCS operators and is not anticipated to impact oil and gas production or the cost of fuels for consumers. c. Would 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. This rule would have a negligible economic effect on the OCS oil and gas industry. BOEM has determined that the current costs of implementation of the current USEPA standards would likely not be significant, and that any costs associated with potential future USEPA actions are too speculative for purposes of analysis. Pursuant to section 213(a) of the Small Business Regulatory Enforcement Fairness Act of 1996 (Pub. L. 104–121), we want to assist small entities in understanding this proposed rule so they can better evaluate its effects on them and participate in the rulemaking. If you believe this rule would affect your small business, organization, or governmental jurisdiction and you have questions concerning its provisions or options for compliance, you may contact Peter Meffert, Bureau of Ocean Energy Management Office of Policy, Regulation, and Analysis at Peter.Meffert@boem.gov or mail to PO 00000 Frm 00076 Fmt 4701 Sfmt 4702 45600 Woodland Road, Sterling, Virginia 20166; or call (703)787–1610. 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 to the Regional Small Business Regulatory Fairness Board. 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 BOEM, call 1–888–REG– FAIR (1–888–734–3247). 4. Unfunded Mandates Reform Act of 1995 This rule does not impose on State, local, or tribal governments, or the private sector an unfunded mandate 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 Unfunded Mandates Reform Act (2 U.S.C. 1531 et seq.) is not required. B. Executive Orders (E.O.) and Presidential Memorandum 1. Governmental Actions and Interference With Constitutionally Protected Property Rights (E.O. 12630) March 15, 1988 According to E.O. 12630, this proposed rule does not have significant takings implications. The rulemaking is not a governmental action capable of interfering with constitutionally protected property rights. A Takings Implication Assessment is not required. 2. Regulatory Planning and Review (E.O. 12866) October 4, 1993 The OMB has reviewed this rulemaking under section 6(a)(3) of E.O. 12866. OMB has determined this proposed rule is significant because it will potentially raise novel legal or policy issues. This rulemaking is not economically significant. Executive Order 12866 provides the Office of Information and Regulatory Affairs (OIRA) within OMB will review all significant rules. To the extent permitted by law, each agency must, among other things: (a) Propose or adopt a regulation only upon a reasoned determination that its benefits justify its costs (recognizing some benefits and costs are difficult to quantify); (b) tailor its regulations to impose the least burden on society, consistent with attaining regulatory objectives, taking into account, among other things, and to E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules the extent practicable, the costs of cumulative regulations; (c) select, in choosing among alternative regulatory approaches, those approaches that maximize net benefits (including potential economic, environmental, public health and safety, and other advantages; distributive benefits; and equity); (d) to the extent feasible, specify performance objectives, rather than specifying the behavior or manner of compliance that regulated entities must adopt; and (e) identify and assess available alternatives to direct regulation, including providing economic incentives to encourage the desired behavior, such as user fees or marketable permits, or providing information with which choices can be made by the public. (1) The proposed requirements in this rule would not have an effect of $100 million or more per year on the economy. The proposed rule would alter requirements for reporting emissions in an operator’s exploration or development plan. The proposed rule also would require more accurate estimating and reporting of the emissions associated with offshore operations. The compliance costs for this rulemaking primarily relate to air dispersion and photochemical grid modeling, air pollutant emissions monitoring, air quality monitoring and the implementation of emission reduction measures (including the use of emissions credits). The remaining compliance costs are for additional paperwork burden hours identified in the section of the preamble on the PRA for Operators submitting EPs and DOCDs or DPP pipeline Rights-of-Way ROW, RUE and lease term pipeline applications. BOEM estimates the industry compliance costs for activities in the first year will be $23 million, the peak year (2020) $49 million and $290 million over 10 years discounted at 3 percent. The government staffing costs are estimated to be about $1.6 million per year and $12 million over 10 years discounted at 3 percent. BOEM estimates the total first year compliance cost for both the regulated industry and the government is $23.6 million, $51 million for the peak year and over 10 years is $302 million discounted at 3 percent. Additional information on the compliance costs can be found in the rulemaking’s draft RIA posted in the docket. The qualitative benefits for the proposed regulatory changes would be VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 the improved ability to ensure the continued development of offshore facilities does not adversely impact any State, including its human population, economy and environment, as well as the improved information BOEM and States will receive regarding the expected air quality impacts onshore and above State submerged lands from OCS exploration and development. The proposed regulatory changes will require more accurate emissions information resulting from BOEMauthorized operations in both the Arctic and GOM. This improved air emission information will better ensure BOEM only approves plans that meet the requirements of the OCSLA (43 U.S.C. 1331 et seq., Pub. L. 83–212, as amended), to ensure compliance with the NAAQS to the extent that these operations do not significantly affect the air quality of any State. The proposed rule would strengthen the requirements for identifying, modeling, measuring and tracking the emissions of air pollutants. Coastal States and other stakeholders can thereby be more confident regarding the expected onshore air quality impacts from OCS oil and gas exploration and development. The additional monitoring information required for certain plans will also permit the BSEE to better assess the air quality compliance for OCS operations on a plan-by-plan basis. Based on a consideration of the qualitative as well as quantitative factors related to the rulemaking proposal, BOEM’s assessment is that it is necessary to achieve compliance with the requirements of the OCSLA and that the proposed rule’s adoption would provide a net benefit to the public. The additional monitoring information required for certain plans will also permit the BSEE to better assess the air quality compliance for OCS operations on a plan-by-plan basis. The table below summarizes BOEM’s estimate of the 10-year quantifiable net benefits. BOEM has only estimated the quantified benefits of NOX reductions. The greatest compliance cost and NOX reduction benefits are expected for deepwater projects, especially in the Mississippi Canyon area. The quantifiable benefits are estimated to range from $8 million to $43 million per year and are attributed to the NOX reductions due to ERMs or emissions credits on those few projects that are expected to require emission reductions. PO 00000 Frm 00077 Fmt 4701 Sfmt 4702 19793 The bureau’s analysis did not quantify other benefits that are too difficult to estimate in concrete fiscal terms. Additional information on the compliance costs and benefits can be found in the IRIA. Even though the quantified net benefits are negative in most years, these benefits do not reflect the full implications of the impact that the rule will have overall. First, the rule could result in the reduction of VOCs, SOX, CO, and PM emissions if operational controls are required as a condition of BOEM plan approval that would not otherwise be employed by operators. These potential reductions have not been quantified because BOEM believes most operators will voluntarily utilize operational controls including best combustion practices due to fuel savings. Second, the rule could result in a lower rate of O3 and PM formation onshore than those which have been quantified because there are likely to be reductions in O3 and PM formation rates associated with non-NOX reductions in precursor air emissions.92 Third, the rule is necessary in order to ensure continued compliance with the mandates of OCSLA and, as such, is essential to the continued development of oil and gas resources on the OCS. Fourth, the elimination of the mandate to use BACT as an emissions control will allow lessees and operators to utilize offsets whenever they are cheaper. This unquantified benefit would directly reduce the compliance costs of this rule, as compared to the current regulations. Finally BOEM believes the other qualitative benefits referred to in the RIA, such as the potential reduction in compliance costs 93 associated with this rulemaking and the superior environmental effects of implementing offsets onshore rather than offshore, will be more than sufficient to provide on overall positive benefit and justification for this rulemaking. 92 In addition to reductions in the rate of O3 formation resulting from NOX emissions reductions, there could also be reductions in the rate of O3 formation by unquantified reductions in VOCs. In addition, there could be additional reductions in the rate of PM formation that are due to unquantified reductions in non-NOX PM precursors. 93 Examples of this include, the ability to substitute offsets for BACT in cases where the offsets would be more cost effective and allowing offsets to be established onshore, where they are likely to be less expensive and more environmentally beneficial, rather than offshore. E:\FR\FM\05APP2.SGM 05APP2 19794 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules ESTIMATED AD82 ANNUALIZED RULEMAKING NET BENEFITS Millions $, years 2017 Estimated Industry Compliance Costs ......................... Estimated Benefit (NOX Reductions) ............................ asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Estimated Net Benefit .... 2018 2021 2022 2023 2024 2025 2026 $29.9 $35.9 $49.4 $45.1 $36.6 $31.5 $31.7 $27.7 $28.4 $26.5 $35.3 $43.1 $43.1 $34.3 $18.6 $8.8 $7.8 $0.0 $0.0 $3.5 $5.4 $7.2 ¥$6.3 ¥$10.8 ¥ $18.0 ¥$22.7 ¥$23.9 ¥$27.7 ¥$28.4 94 USEPA has issued guidance recommending a SIL for the 1-hour NO2 NAAQS, which it published at: https://www3.epa.gov/nsr/documents/ 20100629no2guidance.pdf. 22:26 Apr 04, 2016 2020 $22.9 BOEM does not expect that the proposed regulatory changes will be unduly burdensome to industry. The proposed requirements are intended to improve BOEM’s review and approval of planned operations by requiring more accurate information and better assessments of the air quality impacts from OCS oil and gas operations. While many of the proposed regulatory changes require additional information from operators, the changes are not expected to increase the incidences of mechanical BACT on OCS facilities. BOEM expects that plans usually will employ ERMs and emissions credits as a response to failing to meet exemption thresholds. Mechanical BACT emission controls or other ERMs may be required for some projects due to the proposed requirements in this rulemaking if emissions credits are not available. Other exploration or development projects may require ERMs due to changes in the USEPA 1-hour NOX standard 94 or changes to the O3 standard. (2) The proposed rule would not adversely affect in a material way the economy, productivity, competition, jobs, the environment, public health or safety, or State, local, or tribal governments or communities. The changes proposed in this rule would strengthen the environmental safeguards and provide additional information to BOEM and coastal States to assess potential impacts to air quality. As discussed in the E.O. 13175 Consultation and Coordination with Indian Tribal Governments section of this preamble, BOEM will hold consultation meetings in Alaska. (3) This proposed rule would not create a serious inconsistency or otherwise interfere with an action taken or planned by another agency. BOEM has consulted with the BLM, FWS, NPS, the Forest Service of the Department of Agriculture, and the USEPA and has proposed changes to align its regulations with those of the BLM, FWS, VerDate Sep<11>2014 2019 Jkt 238001 the NPS and the USEPA where applicable. While the proposed rule would allow the use of the MARPOL emissions standards as proxies for marine diesel engine emission factors for marine engines, the USCG and the USEPA will continue to enforce any applicable emissions limits on vessels. The proposed regulatory changes would improve the information available and facilitate BLM, FWS and NPS analysis regarding the air quality impacts on Class II areas and endangered species. (4) This proposed rule would not alter the budgetary effects of entitlements, grants, user fees, or loan programs or the rights or obligations of their recipients. (5) This proposed rule potentially raises novel legal or policy issues regarding consistency with other federal agencies or international vessel requirements. The novel legal and policy issues are the change in attributed emissions for plans as well as the proposed relocation of the compliance boundary from the shoreline to the offshore submerged lands (State seaward) boundary used for determining exemptions from more detailed air quality analysis and/or modeled compliance with NAAQS. This proposed rule formalizes the methodology for attributed emissions. The 25-mile radius traditionally used by BOEM will no longer apply; the projected emissions calculations account for all emissions supporting a plan’s activity, including in certain cases support emissions from aircraft and onshore facilities. BOEM has linked its air quality regulations, where applicable, to those of other agencies in multiple areas. Many USEPA standards have been explicitly cited and referenced. The Marine Pollution Convention (MARPOL) standards, which are covered in USEPA and USCG regulations, are incorporated. The BLM, FWS, NPS, and the Forest Service of the Department of Agriculture programs to maintain AQRVs, as part of the FLM process, have been explicitly referenced in the BOEM regulations. In addition, informal consultations have and will continue to take place with other federal and State agencies. PO 00000 Frm 00078 Fmt 4701 Sfmt 4702 We have developed this proposed rule consistently with these requirements. The proposed changes in this rulemaking would update and better conform BOEM’s air quality regulations to the requirements of OCSLA. The proposed air quality requirements would automatically be updated as the USEPA changes its standards with respect to which pollutants are potentially harmful and at what levels of exposure those pollutants cause harm. The proposed rule would replace various provisions in the current regulations with more comprehensive and up-to-date provisions based upon more recent science and technology. The rulemaking would better address DOI’s mandate to evaluate the potential impact of any OCS development with respect to the probable impacts to most closely affected States. 3. Civil Justice Reform (E.O. 12988) February 7, 1996 This proposed rule complies with the requirements of E.O. 12988. Specifically, this proposed rule: (a) Meets the criteria of section 3(a) requiring 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. 4. Protection of Children From Environmental Health and Safety Risks (E.O. 13045) April 21, 1997 We have analyzed this proposed rule under E.O. 13045, Protection of Children from Environmental Health Risks and Safety Risks. The USEPA has determined, and BOEM agrees, that children are an at-risk group for health effects associated with exposures to certain air pollutants, including some pollutants released or formed from OCS operations. This proposed rule addresses those air pollutants of greatest concern. BOEM welcomes additional comments on this topic and whether, or to what extent, the proposed rule addresses these relevant issues. E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules This proposed rule is not an economically significant rule and does not create an environmental risk to health or a risk to safety that may disproportionately affect children. 5. Federalism (E.O. 13132) August 10, 1999 Under the criteria in E.O. 13132, this proposed rule would not have any substantial federalism implications. This proposed rule would not substantially and directly affect the relationship between the federal and State governments. To the extent that State and local governments have a role in OCS activities, this proposed rule would not have any significant effect on that role. A separate federalism assessment is not required and has not been prepared. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 6. Consultation and Coordination With Indian Tribal Governments (E.O. 13175) November 6, 2000 DOI 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. BOEM has evaluated this proposed rule under the Department’s consultation policy and under the criteria in Executive Order 13175 and has determined this proposed rule would not cause a substantial direct or adverse effect on any Federally-recognized Indian tribe. There are a number of reasons why BOEM has come to this conclusion. There are many circumstances whereby the proposed rule has strengthened the requirements for identifying, measuring and tracking the emissions of air pollutants and no circumstances in which the proposed rule would relax or lessen any existing air quality requirements or standards. The proposed rule would incorporate the various enhancements to the current BOEM air quality regulatory process, including but not limited to the following: • The proposed rule would incorporate all key USEPA air quality standards and benchmarks by direct cross-reference. Thus, BOEM’s proposed regulations would both reflect current USEPA standards and would be updated automatically in the future if a new air quality standard or benchmark were to be promulgated by the USEPA. • The proposed rule expands the circumstances under which emissions from MSCs would be accounted for in both exploration and development plans. MSC emissions would be tracked and reported whenever a vessel would be operating in support of a regulated facility, regardless of its distance from that facility. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 The proposed rule would enhance the accuracy of the evaluation of emissions from support vessels by measuring all such emissions from the point at which they occur. The proposed rule mandates all potentially significant emitters of air pollutants maintain fuel logs, which can be used to calculate their potential emissions. This proposed rule contains new provisions for mandatory stack testing or the installation of meters when the Regional Supervisor determines emissions estimates may be unreliable or inaccurate. In circumstances where a lessee or operator proposes to use equipment that is not compliant with the USEPA requirements, the proposed rule would require the lessee or operator to obtain relevant air pollutant emissions data from the equipment manufacturer or, alternately, to test the actual level of pollutants that are emitted. The proposed rule does reflect changes Congress made with respect to the CAA when it granted Federallyrecognized Indian tribes the right to regulate the air quality over their territories independently from the States. If such a tribe has been granted the authority to regulate its own air quality, by issuing air quality permits in lieu of the States, or if the tribe has implemented a tribe-wide air quality implementation plan to which new permit applicants must comply, BOEM would recognize this authority and grant the tribes the same authority as a State to appeal BOEM’s approval of plans for OCS development activities. This authority would not be extended to all tribes, however, since a tribe may elect not to establish any air quality regulatory scheme. In the event that a tribe has not established its own air quality regulatory mechanism, there is no reason that it should have the same rights as a State under BOEM’s regulations. Such a tribe would, of course, retain all the rights of public comment on rulemakings and to provide feedback to BOEM at public forums. Although BOEM does not believe this proposed rule would cause any substantial direct or adverse impact to any Indian tribe, in order to inform such Indian tribe(s), DOI intends to initiate consultations with potentially affected tribe(s) on a government-to-government basis during the public comment period for this rule. BOEM will fully consider all tribal views and concerns before issuing a final rule on this topic. PO 00000 Frm 00079 Fmt 4701 Sfmt 4702 19795 7. Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution or Use (E.O. 13211) May 18, 2001 We have analyzed this proposed rule under E.O. 13211, ‘‘Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use’’ and have determined this rule is not a significant energy action under the definition in Executive Order 13211. The IRIA provides a general discussion of modeling, monitoring and emission reduction compliance costs on potentially marginal GOM development projects. 8. Enhancing Coordination of National Efforts in the Arctic (E.O. 13689) January 21, 2015 E.O. 13689 recognizes the Arctic has critical long-term strategic, ecological, cultural, and economic value, and it is imperative we continue to protect our national interests in the region, which include: National defense; sovereign rights and responsibilities; maritime safety; energy and economic benefits; environmental stewardship; promotion of science and research; and preservation of the rights, freedoms, and uses of the sea as reflected in international law. E.O. 13689 also recognizes it is vital that federal agencies work together to enhance coordination on Arctic efforts. Pursuant to this goal, the E.O. establishes an Arctic Executive Steering Committee (Steering Committee), to provide ‘‘guidance to executive departments and agencies (agencies) and enhance coordination of federal Arctic policies across agencies and offices, and, where applicable, with State, local, and Alaska Native tribal governments and similar Alaska Native organizations, academic and research institutions, and the private and nonprofit sectors.’’ DOI is a member of this Steering Committee. Consistent with DOI’s long-standing commitment to coordinate with other federal agencies on Artic matters, BOEM will work with the Steering Committee and other relevant agencies, including the USEPA, BSEE, FWS, NPS, BLM, and the Forest Service within the Department of Agriculture. The E.O. also recognizes ‘‘it is in the best interest of the Nation for the Federal Government to maximize transparency and promote collaboration where possible with the State of Alaska, Alaska Native tribal governments and similar Alaska Native organizations, and local, private-sector, and nonprofitsector stakeholders.’’ BOEM intends to take action consistent with this E:\FR\FM\05APP2.SGM 05APP2 19796 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS objective in order to ensure the implementation of the underlying goals. 9. Improving Regulation and Regulatory Review (E.O. 13563) January 18, 2011 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 regulations must be based on the best available science and the rulemaking process must allow for public participation and an open exchange of ideas. We have developed this rulemaking in a manner consistent with these requirements. Executive Order 13563 also calls for consideration regarding a regulation’s impact on employment. It states, ‘‘Our regulatory system must protect public health, welfare, safety, and our environment while promoting economic growth, innovation, competitiveness, and job creation.’’ An analysis of employment impacts is a standalone analysis, and these impacts are not included in the estimation of benefits and costs. BOEM does not expect the proposed rule’s compliance cost will be great enough to close operations or prevent new ones from starting. However, employment reductions are possible in related activities if operators chose to slow development due to the provisions of this rulemaking. On the other hand, actions taken to comply with this proposed rule also will create employment opportunities; for example, consulting firms specializing in air quality analysis and modeling are likely to experience increased employment demand. As more companies need to model and maintain records of their emissions, new employment opportunities in the broad field of air quality analysis will emerge. While BOEM does not anticipate that companies will adopt an emission reduction measure like post-combustion SCR, the companies that install these mitigation technologies would benefit from increased demand for their equipment. The proposed rule is not expected to generate either large negative or positive employment impacts. On balance, there will likely be adjustments on both sides VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 among companies directly and indirectly affected by the regulation. As stated in E.O. 12866, to the extent permitted by law, each agency must, among other things: (1) Propose or adopt a regulation only upon a reasoned determination its benefits justify its costs (recognizing some benefits and costs are difficult to quantify); (2) tailor its regulations to impose the least burden on society, consistent with attaining regulatory objectives, taking into account, among other things, and to the extent practicable, the costs of cumulative regulations; (3) select, in choosing among alternative regulatory approaches, those approaches that maximize net benefits (including potential economic, environmental, public health and safety, and other advantages; distributive benefits; and equity); (4) to the extent feasible, specify performance objectives, rather than specifying the behavior or manner of compliance that regulated entities must adopt; and (5) identify and assess available alternatives to direct regulation, including providing economic incentives to encourage the desired behavior, such as user fees or marketable permits, or providing information with which choices can be made by the public. BOEM has evaluated these options and made the determination there is no alternative that meets the need for this rulemaking and the proposed rulemaking is the best alternative for addressing the important policy objectives that BOEM is pursuing. The proposed changes in this rulemaking would better ensure that BOEM’s air quality regulations conform to the requirements of OCSLA. Unlike the current regulations, the proposed air quality requirements would automatically be updated if the USEPA changed its standards as to which pollutants are potentially harmful and at what levels of exposure those pollutants cause harm. The proposed rule would replace various provisions in the current regulations with more comprehensive and up-to-date provisions based upon more recent science and technology. The rule would better address DOI’s mandate to evaluate the potential impact of any OCS development with respect to the probable impacts to most closely affected States. 10. Presidential Memorandum of June 1, 1998 on Regulation Clarity E.O. 12866 (section 1(b)(2)), E.O. 12988 (section 3(b)(1)(B)), E.O. 13563 (section 1(a)), and the Presidential Memorandum of June 1, 1998, require every agency write its rules in plain language. This means that, wherever PO 00000 Frm 00080 Fmt 4701 Sfmt 4702 possible, each rule must: (a) Have a logical organization; (b) use the active voice to address readers directly; (c) use common, everyday words and clear language, rather than jargon; (d) use short sections and sentences; and (e) maximize the use of lists and tables. If you feel we have not met these requirements, send your comments to Peter.Meffert@boem.gov. To better help BOEM revise the proposed rule, your comments should be as specific as possible. For example, you should tell us the number of any section or paragraph that you think we wrote unclearly, which section(s) or sentence(s) are too long, or the section(s) where you believe lists or tables would be useful, etc. Public Availability of Comments We will post all comments, including names and addresses of respondents, at www.regulations.gov. Before including your address, phone number, email address, or other personal identifying information in your comment, you should be aware we may make your entire comment—including your personal identifying information— publicly available at any time. While you can ask us in your comment to withhold your personal identifying information from public view, we cannot guarantee we will be able to do so. List of Subjects in 30 CFR Part 550 Administrative practice and procedure, Air pollutant, Air pollution, Air quality, Arctic, Attainment area, Continental shelf, Compliance, Criteria pollutants, Development plan, Development and production plan, Environmental assessments, Environmental impact statements, Environmental protection, Exploration plan, Federal lands, Federal Land Manger, Greenhouse gasses, Hazardous air pollutants, Incorporation by reference, New source review, Nonattainment area, Oil and gas exploration, Oil and gas development, Oil pollution, Oil production, Outer Continental Shelf, Ozone, Penalties, Pipelines, Precursor pollutants, Prevention of significant deterioration, Reporting and recordkeeping requirements, Sulphur. Dated: March 11, 2016. Amanda C. Leiter, Acting Assistant Secretary—Land and Minerals Management. For the reasons stated in the preamble, the Bureau of Ocean Energy Management, (BOEM) proposes to amend 30 CFR part 550 as follows: E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules primary or secondary National Ambient TABLE TO § 550.102—WHERE TO FIND INFORMATION FOR CON- Air Quality Standards (NAAQS), in 40 CFR part 50, pursuant to section 109 of DUCTING OPERATIONS—Continued PART 550—OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF 1. The authority citation for 30 CFR part 550 is revised to read as follows: ■ For information about Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 43 U.S.C. 1334. (12) Oil and gas wellworkover operations. Subpart A—General (13) Platforms and structures 2. Revise the section heading for § 550.101 to read as follows: ■ § 550.101 ■ (14) Rights-of-Use and Easement (RUE). Applicability. 3. Revise § 550.102 to read as follows: § 550.102 TABLE TO § 550.102—WHERE TO FIND INFORMATION FOR CONDUCTING OPERATIONS (1) Applications for permit to drill (APD). (2) Development and Production Plans (DPP) and Development Operations Coordination Documents (DOCD). (3) Downhole commingling ... asabaliauskas on DSK3SPTVN1PROD with PROPOSALS (15) Pipelines and Pipeline Rights-of-Way (ROW). What does this part do? (a) 30 CFR part 550 contains the regulations of the BOEM Offshore program that govern oil, gas and sulphur exploration, development and production operations on the Outer Continental Shelf (OCS). These regulations may require you, when conducting operations on the OCS, to submit plans, requests, applications, and notices, and, upon request, to submit supplemental information. (b) The following table of general references shows where to look for information about these processes. For information about Refer to 30 CFR part 250, subpart D. 30 CFR part 550, subpart B. 30 CFR part 250, subpart K. (4) Exploration Plans (EP) .... 30 CFR part 550, subpart B. (5) Flaring .............................. 30 CFR part 250, subpart K. (6) Gas measurement ........... 30 CFR part 250, subpart L. (7) Off-lease geological and 30 CFR part geophysical (G&G) Permits. 551. (8) Oil Spill Financial Re30 CFR part sponsibility (OSFR) cov553. erage. (9) Oil and gas production 30 CFR part safety systems. 250, subpart H. (10) Oil spill response plans 30 CFR part 254. (11) Oil and gas well-comple- 30 CFR part tion operations. 250, subpart E. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 19797 (16) Sulphur operations ........ (17) Training .......................... (18) Unitization ...................... (19) Air Quality ...................... Refer to 30 CFR part 250, subpart F. 30 CFR part 250, subpart I. 30 CFR part 550, subpart A. 30 CFR part 250, subpart J and 30 CFR part 550, subpart J. 30 CFR part 250, subpart P. 30 CFR part 250, subpart O. 30 CFR part 250, subpart M. 30 CFR part 550, subpart C. 4. Revise § 550.105 as follows: a. Revise the definition of ‘‘Air pollutant’’; ■ b. Delete the definitions of ‘‘Attainment area’’, ‘‘Best available control technology’’, and ‘‘Emission offsets’’; ■ c. Add a definition for ‘‘Emissions source’’; ■ d. Delete the definitions of ‘‘Existing facility’’ and ‘‘Facility’’; ■ e. Add a definition for ‘‘Federal Land Manager,’’ ■ f. Revise the definitions of ‘‘Flaring’’ and ‘‘Minerals’’; ■ g. Add a definition for ‘‘Mobile support craft’’; ■ h. Delete the definition of ‘‘Nonattainment area’’; ■ i. Add a definition for ‘‘Offshore vehicle’’; ■ j. Delete the definition of ‘‘Projected emissions’’; ■ k. Remove the definition for ‘‘Right-ofuse’’ and add in its place a definition for ‘‘Right-of-use and easement (RUE)’’; ■ l. Add a definition for ‘‘State’’; and ■ m. Revise the definition of ‘‘Venting’’. The revisions and additions read as follows: ■ ■ § 550.105 Definitions. * * * * * Air pollutant means any of the following: (1) Any criteria pollutant for which the U.S. Environmental Protection Agency (USEPA) has established PO 00000 Frm 00081 Fmt 4701 Sfmt 4702 the Clean Air Act (CAA); (2) Any precursor air pollutant identified by the USEPA that contributes to the formation of a criteria pollutant through a photochemical or other reaction, including, but not limited to, Volatile Organic Compounds (VOCs), ammonia (NH3), and those criteria pollutants (CPs) that are also precursors for other CPs (such as sulphur dioxide (SO2)); (3) any USEPA-defined Greenhouse Gas (GHG), as defined at 40 CFR 98.6, pursuant to section 111 of the CAA; and (4) Any USEPA-defined Hazardous Air Pollutant, as defined at 40 CFR 63.2, pursuant to section 112 of the CAA. * * * * * Emissions source means a device or substance that emits air pollutant(s) in connection with any authorized activity described in your plan. Several emissions sources may exist on a single facility, aircraft, vessel, or vehicle. Anything that: Produces or results in the release of one or more air pollutant(s), including the flashing, flaring or venting of natural gas, involves burning any oil or well test fluids, or generates fugitive emissions, is an emissions source. Examples include, but are not limited to: Boilers/heaters/burners, diesel engines, drilling rigs, combustion flares, cold vents, glycol dehydrators, natural gas engines, natural gas turbines, pneumatic pumps, pressure/level controllers, amine units, tanks, dual fuel turbines, sources involved in mud degassing, storage tanks, well testing equipment, vessels (including support vessels, pipeline lay barges, pipeline bury barges, derrick barges), and any other equipment that could cause fugitive emissions, venting, losses from flashing, or loading losses. * * * * * Federal Land Manager (FLM) means the Secretary of the Department with authority over any federal Class I area or sensitive Class II area (or the Secretary’s designee). Flaring means the burning of natural gas or other hydrocarbons and the release of the associated emissions into the atmosphere. The term ‘‘flaring’’ is equivalent to combustion flaring (i.e., burning of the gases), but is distinct from cold venting, which involves the discharge of raw pollutants into the air without burning. * * * * * Minerals includes oil, gas, sulphur, geopressured-geothermal and associated resources, and all other minerals that E:\FR\FM\05APP2.SGM 05APP2 19798 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules are authorized by an Act of Congress to be produced from public lands. * * * * * Mobile support craft (MSC) means any offshore supply vessel (OSV) as defined by the USCG in accordance with 46 U.S.C. 2101, and any ship, tanker, tug or tow boat, pipeline barge, anchor handling vessel, facility installation vessel, refueling or ice management vessel, oil-spill response vessel, or any other offshore vessel, remotely operated vehicle (ROV), or any offshore vehicle used by, or in the support of, the offshore operations described in a plan. For the purpose of evaluating air emissions, an MSC is considered a facility while temporarily attached to the seabed or connected to another facility. * * * * * Offshore vehicle means a type of MSC that is capable of being driven on ice and which provides support services or personnel to your facility or facilities. * * * * * Right-of-use and easement (RUE) means seabed use authorization, other than an OCS lease, that BOEM may grant at an OCS site pursuant to §§ 550.160 through 550.166 of this part. * * * * * State means any State of the United States (U.S.) extending to the limit of the State seaward boundary (SSB), as defined in 43 U.S.C. 1301(b). * * * * * Venting means the release of gas into the atmosphere, including though a stack without igniting it, whereby relief flows of natural gas or other hydrocarbons are directed to an unignited flare or which are otherwise discharged directly to the atmosphere. This includes gas that is released underwater and bubbles to the atmosphere. * * * * * ■ 5. In § 550.141, add paragraphs (d) and (e) and revise the title to read as follows: § 550.141 May I use or be required to use alternate procedures or equipment? asabaliauskas on DSK3SPTVN1PROD with PROPOSALS * * * * * (d) In order to protect public health, you may be required or allowed by the Regional Supervisor to temporarily suspend the use of equipment that emits air pollutants, or to implement operational control(s) on the use of such equipment, when an adjacent State or locality declares an air quality episode or emergency, provided that any such suspension or operational control(s) would not cause an immediate threat to safety or the environment. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 (e) With respect to published documents cited in these regulations, including those incorporated by reference in § 550.198, the following provisions apply: (1) In each instance, the applicable document is the one specifically referred to, including any referenced supplement or addendum, and not any other version, supplement or addendum, even if by the same author, agency or publisher. You may comply with a later edition of a specific document incorporated by reference, provided you show that complying with the later edition provides a degree of scientific or technical accuracy, environmental protection, or performance equal to or better than would be achieved by compliance with the listed edition; and you obtain the prior written approval for alternative compliance from the authorized BOEM official. (2) In the case of USEPA documents, you may always use the most recent version approved by the USEPA. ■ 6. In § 550.160, redesignate current paragraphs (f), (g), (h) and (i) as paragraphs (g), (h), (i) and (j) respectively, and add a new paragraph (f) to read as follows: § 550.160 When will BOEM grant me a right-of-use and easement, and what requirements must I meet? * * * * * (f) If you apply for a RUE with a facility as defined in § 550.302 or you hold a RUE with such a facility, then you must submit the information required by § 550.205, except that the ten-year periodic review requirement in § 550.310(c) may be waived by the Regional Supervisor. For the purposes of this section, any provisions of those sections applicable to a lessee or operator should be read to refer equally to any RUE applicant or any holder thereof. If the RUE is approved or held as part of an existing or proposed plan, no additional air quality requirements would apply to the plan. * * * * * ■ 7. Add § 550.187 to subpart A to read as follows: § 550.187 What region-wide offshore air emissions data must I provide? (a) OCS emissions inventory. You, as a lessee, an operator, or a holder of a RUE or pipeline ROW (whether or not that ROW includes an accessory structure), must collect and maintain information regarding all air pollutant emissions from all emissions sources associated with your operations. You must retain this information for a period of no less than 10 years. You must PO 00000 Frm 00082 Fmt 4701 Sfmt 4702 submit this information to the appropriate regional office on an ongoing basis according to a schedule corresponding to the schedule for the National Emissions Inventory as established by the USEPA. If you have an emissions source that generates facility emissions that have a potential to emit (PTE) such that it would qualify as a Type A source according to USEPA’s regulations in table 1 of appendix A of subpart A (‘‘Emission Thresholds by Pollutant for Treatment as Point Source’’) of 40 CFR 51.50, then, beginning in either 2017 or the next reporting period after [EFFECTIVE DATE OF THE FINAL RULE], you must report this information according to the timeframes specified in 40 CFR 51.30(b). (b) The information provided must include the emissions of or the activity data necessary to calculate the emissions of stationary emissions sources, including all facilities, and all non-stationary sources, including MSC(s) and any other non-stationary emissions source(s) of air pollutants above the OCS or above State submerged lands that operate in support of your facility or facilities, as determined by the Regional Supervisor. You may request that the owner of such non-stationary emissions source(s) provide the information to BOEM or a BOEM-designated agent, but if the owner does not provide the information, the lessee, operator, or RUE or pipeline ROW holder is still responsible for submitting the required information. (c) As part of the information required in this section, you must submit, in a form and manner as specified by the Regional Supervisor: (1) Your facility and equipment usage, including hours of operation at each percent of capacity for each emissions source; and/or (2) Your monthly and annual fuel consumption showing the quantity, type, and sulphur content of fuel used for each emissions source that generates air pollutants in connection with operations on the OCS. (3) The information provided should be at a sufficient level of detail so as to facilitate BOEM’s compilation of a comprehensive OCS emissions inventory of air pollutants. (4) You must classify the emissions according to the appropriate Source Classification Codes (SCCs) as defined by the USEPA in FIRE Version 5.0: Source Classification Codes and Emission Factor Listing for Criteria Air Pollutants, incorporated by reference in § 550.198(b)(1)(iv). (d) The Regional Director may waive or permit delay in compliance with the E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules requirements of this section on a regionwide basis. ■ 8. Add § 550.198 to read as follows: asabaliauskas on DSK3SPTVN1PROD with PROPOSALS § 550.198 Documents incorporated by reference. (a) (1) Certain material is incorporated by reference into this part with the approval of the Director of the Federal Register under 5 U.S.C. 552(a) and 1 CFR part 51. In each instance, the applicable document is the one specifically referred to, including any referenced supplement or addendum, and not any other version, supplement or addendum, even if by the same author, agency or publisher. To enforce any edition other than that specified in this section, BOEM will publish a document in the Federal Register and the material will be available to the public. All approved material is available for inspection at the Bureau of Ocean Energy Management, Office of Policy, Regulation and Analysis, 45600 Woodland Road, Sterling, Virginia 20166 or by phone at (703) 787–1610, and is available from the sources listed below. It is also available for inspection at the National Archives and Records Administration (NARA). For information on the availability of this material at NARA, call 202–741–6030, or refer to: https://www.archives.gov/ federal_register/code_of_federal_ regulations/ibr_locations.html. (2) The effect of incorporation by reference of a document into the regulations in this part is that the incorporated document is a regulatory requirement. When a section in this part incorporates all of a document, you are responsible for complying with the provisions of that entire document, except to the extent that the section which incorporates the document by reference provides otherwise. When a section in this part incorporates part of a document, you are responsible for complying with that part of the document as provided in that section. BOEM incorporated each document or specific portion by reference in the sections noted. The entire document is incorporated by reference, unless the text of the corresponding sections in this part calls for compliance with specific portions of the listed documents. In each instance, the applicable document is the specific edition or specific edition and supplement or addendum cited in this section. (b) Environmental Protection Agency, Office of Air and Radiation, 1200 Pennsylvania Ave. NW., MS6101A, Washington, DC 20460. (1) AP 42, Fifth Edition, Compilation of Air Pollutant Emission Factors, VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Volume 1: Stationary Point and Area Sources, January 1995, incorporated by reference at § 550.205(b. (2) Motor Vehicle Emission Simulator (MOVES), User Guide, Assessment and Standards Division, Office of Transportation and Air Quality, EPA– 420–B–14–055, July 2014, incorporated by reference at § 550.205(b). (3) User’s Guide for the Final NONROAD2005 Model, EPA420–R–05– 013, December 2005 incorporated by reference at § 550.205(b). (4) FIRE (Factor Information Retrieval System) Version 5.0: Source Classification Codes and Emission Factor Listing for Criteria Air Pollutants, EPA 454/R–95–012, August 1995, incorporated by reference at § 550.187(c). (c) Federal Aviation Administration (FAA), Office of Environment and Energy, (AEE–100), 800 Independence Avenue SW., Washington, DC 20591. (1) Aviation Environmental Design Tool (AEDT) User’s Guide, Version 2B, July 2015 (as amended) incorporated by reference at § 550.205(b). (2) Aviation Environmental Design Tool (AEDT), Version 2B, AEDT Standard Input File (ASIF) Reference Guide, May 2015 (as amended) incorporated by reference at § 550.205(b). (d) International Maritime Organization, 4 Albert Embankment, London SE1 7SR, United Kingdom, or https://www.imo.org, or 44–(0)20–7735– 7611. (1) Revised MARPOL (Marine Pollution) Annex VI, Regulations for the Prevention of Air Pollution from Ships, and NOX Technical Code [NTC] 2008, 2009 edition, incorporated by reference at § 550.205(b). (2) Revised MARPOL Annex VI, Regulations for the Prevention of Pollution from Ships (‘‘2008 Annex VI’’), incorporated by reference at § 550.205(b. (3) NOX Technical Code 2008, incorporated by reference at § 550.205(b). Subpart B—Plans and Information § 550.200 [Amended] 9. Remove the definition of ‘‘Offshore vehicle’’ from § 550.200: ■ 10. Add § 550.205 to read as follows: ■ § 550.205 What air emissions information must be submitted with my Plan (EPs, DPPs, DOCDs, or application for a RUE, pipeline ROW, or lease term pipeline)? All of the terms used in this section have the meaning described in § 550.302, unless defined in § 550.105. Except if excluded from the Air Quality Regulatory Program (AQRP) by PO 00000 Frm 00083 Fmt 4701 Sfmt 4702 19799 paragraph (o) of this section, the requirements in this section apply to all plans, RUE, pipeline ROW, and lease term pipeline applications submitted in any area of the OCS in which the Secretary of the Interior has authority to regulate air quality on the OCS. Your plan must contain the following criteria air pollutant and major precursor air pollutant emissions information: (a) Emissions sources. You must list and describe every emissions source on or associated with any facility or facilities and MSC(s) described in your plan. This includes each emissions source used during the construction, installation (including well protection structure installation), and operation of any exploration, testing, drilling (including well test flaring), development, or production equipment or facility or facilities (including every platform or manmade island included in your plan). You must account for the air pollutant emissions sources associated with all drilling operations, including workovers and recompletions, sidetracking and from pipeline construction. You must include emissions sources associated with your use of oil or gas produced from your lease. The list of emissions sources must cover the duration of the plan’s proposed activities. (1) For each emissions source, you must identify, to the extent practicable: (i) Equipment type and number, manufacturer, make and model, location, purpose (i.e., the intended function of the equipment and how it would be used in connection with the proposed activities covered by the plan), and physical characteristics; (ii) The type and sulphur content of fuel stored and/or used to power the emissions source; and (iii) The frequency and duration of the proposed use. (2) For every engine on each facility, including non-road engines, marine propulsion engines, or marine auxiliary engines, in addition to the information specified under paragraph (a)(1) of this section, you must identify and provide the engine manufacturer, engine type, and engine identification, and the maximum rated capacity of the engine (given in kilowatts (kW)), if available. If you have not yet determined what specific engine will be available for you to use, you must provide analogous information for an engine with the greatest maximum rated capacity for the type of engine which you will use. If the engine has any physical design or operational limitations and you choose to base your emissions calculations on these limitations, then you must provide E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19800 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules documentation of these physical design or operational limitations. (3) For engines on MSCs, including marine propulsion and marine auxiliary engines, in addition to the information specified under paragraph (a)(1) and (2) of this section, you must provide the engine displacement and maximum speed in revolutions per minute (rpm). If the specific rpm information is not available, indicate whether the rpm would be less than 130 rpm, equal to or greater than 130 rpm but less than 2,000 rpm, or equal to or greater than 2,000 rpm, based on best available information. If the actual MSC engine types needed for calculating emissions are unknown or cannot be verified, assume an MSC possessing the maximum potential emissions for the type of MSC you would typically use for your planned operations. (4) For offshore vehicles, you must provide the information specified under paragraph (a)(1) of this section. If the actual offshore vehicle engine types needed for calculating emissions are unknown or cannot be verified, assume an offshore vehicle possessing the maximum emissions for the types of offshore vehicles you would typically use for your planned operations. (5) For any emissions source not described above, you must provide all information needed to calculate and verify the associated emissions, such as volumes vented, volumes flared, size of tank, and number of components. (b) Emissions factors. For each emissions source identified under paragraph (a) of this section, you must identify the most appropriate emissions factors used to calculate the emissions for every criteria air pollutant and major precursor air pollutant emitted by that source. (1) Emissions testing. You may use actual emissions amounts as measured from emissions testing conducted on a specific emissions source, in lieu of the standards or emissions factors for that source which are described in paragraph (b)(2) of this section. However, if none of the methods in paragraph (b)(2) of this section are applicable, you must conduct stack testing on the emissions source to determine the appropriate emissions factor. The data from stack testing may be used only for the engine for which the stack testing was conducted. When determining the emission factors through testing, you must consider: (i) Test points and procedures. (A) In general, test points should be devised based on actual operations as opposed to using the test points and engine loads contained in one of the various marine duty cycles. If, based on the unique VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 circumstances of the proposed project, this is impracticable, an alternative approach for defining test points may be implemented with the approval of the Regional Supervisor. It cannot be assumed that emissions per hour or emissions per kW hour or horse-power hour from large main engines on drill ships and platforms are highest during full load or near-full load operation. The emissions factor and emission per hour or emissions per kW hour or horsepower hour for the operation that is actually expected should be determined, and the emissions under 90% load should be used only if emissions at this load are the highest and thus conservative. (B) Testing should be done consistent with the procedures outlined in 40 CFR part 53 to the maximum extent practicable. Where the unique circumstances or requirements of the proposed operations make such procedures impracticable, alternative procedures may be implemented with the approval of the Regional Supervisor. As appropriate, you must use the General Provisions for Determining Standards of Performance for New Stationary Sources, at 40 CFR 60.8. (ii) Fuel. You must ensure that the fuel used in the testing to generate the emission factors reflects the type of fuel that will be used by the engine in actual operation and that the sulphur content of the fuel is the same as that which will be used in the engine. (2) In the event that you elect not to measure the actual emissions for any given emissions source, select an emissions factor from one of the following references (references are listed in priority order; you may use a method only if all the methods identified above it are not available): (i) You may use the emissions factor(s) that are vendor-guaranteed or provided by the manufacturer of the specific emissions source, if available; where a manufacturer has not provided an emissions factor for the emissions source you propose to use, you may use a manufacturer’s emissions factor for a similar source only if you can demonstrate to the satisfaction of the Regional Supervisor that the emissions generated by your emissions source are the same as or lower than that for which a manufacturer’s emissions factor is available. If you elect to use vendorguaranteed or manufacturer data, you must demonstrate that: (A) The fuel used by the manufacturer to generate the emission factors reflects the type of fuel that will be used by the engine in actual operation; and, (B) The actual engine has not been modified outside the configuration used PO 00000 Frm 00084 Fmt 4701 Sfmt 4702 to generate the emission factors; thus, the emission factors used in the plan must represent the actual pattern of use for that equipment in operations. (ii) You may use emissions factors generated from source tests required by the USEPA OCS permits as BOEM emission estimates for a specific rig. If emissions factors were not generated through testing for a particular engine, emissions factors generated from a recent and similar permit engine may be used. Data from a rig from the same manufacturer, having an engine of the same model and year is generally allowed, unless the Regional Supervisor has a reason to believe that such data may not be accurate or reliable. (iii) You may use a model or table, as appropriate, developed by the USEPA or FAA, if available and appropriate to the emissions source, and you may use the emissions factors from that model or table. (A) For commercial marine engines operating aboard MSC, excluding vehicles and aircraft, apply emission factors based on the classification of the engine (i.e., category 1, category 2, and category 3), the year the engine was manufactured, and the maximum engine power expressed in kW. Some category 3 engine emission factors are based on rpm rather than maximum engine power. Engine category, year, model, and emission factors, by kW power rating, are given in 40 CFR 1042.101 for category 1 and category 2 commercial engines and consider the useful life provisions of each engine category. Engine category, year, model, and emission factors, by rpm rating, are given in 40 CFR 1042.104 for category 3 commercial marine engines, and also consider the useful life provisions for each engine category. (B) For non-road equipment used on the drill ships or platforms, non-road emission factors, rather than marine engine emission factors may be used. The primary source for these emission factors is the NONROAD portion of the Motor Vehicle Emission Simulator (MOVES) model (https://www.epa.gov/ otaq/models/moves/index.htm), as incorporated by reference at § 550.198. Depending on the type of engine, the NONROAD2008A Model may also be used, as incorporated by reference at § 550.198. That model is available at https://www.epa.gov/otaq/ nonrdmdl.htm. (C) For storage tanks, use the USEPA’s TANKS model, or the most recent USEPA-recommended update or replacement, to generate emission factors, such as the AP 42 Compilation of Emissions Factors, Chapter VII, incorporated by reference at § 550.198. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules (D) In the event that you are required to report emissions data from aircraft, use emissions factors generated by the AEDT, incorporated by reference at § 550.198, or from another appropriate model, or set of models, approved by the FAA, in the event that the AEDT does not contain emissions factors for the relevant aircraft proposed in your plan. AEDT emissions factors are available at: https://www.faa.gov/about/ office_org/headquarters_offices/apl/ research/models/aedt/. (iv) You may use an emission factor from a published study conducted by a reputable source, such as the California Air Resources Board, a university, or research agency, if such source yields reliable emission factors or formula(s) to calculate emissions factors for certain types of engines and equipment other than for the large main engines on drilling ships and drill platforms and for locomotive-sized engines powering cranes. If an emission study is used, the study must cover representative engines, fuels, and duty cycles. (v) For non-U.S. flagged vessels having non-USEPA-certified, MARPOLcertified marine engines, you may use the MARPOL Annex VI standards, available from the International Maritime Organization, incorporated by reference at § 550.198, or the Revised MARPOL Annex VI, Regulations for the Prevention of Pollution from Ships, incorporated by reference at § 550.198, as appropriate taking vessel flag as well as engine size into account when determining the emission factor that should apply to an engine. With respect to calculations specifically for NOX emissions or emissions factors, any reporting must comply with the NOX Technical Code [NTC] 2008 incorporated by reference at § 550.198. If this method is used, the plan must account for any differences in the sulphur limits of the fuel being used and the sulphur limit of the fuel used for emission testing. All fuel used by the subject drilling ships and offshore platforms must either be purchased in the U.S. or comply with applicable CAA fuel emissions requirements, unless the lessee or operator can demonstrate that it has properly accounted for any differences in emissions that may result from the use of non-U.S. fuel. (vi) For a natural gas-powered engine of any rated capacity, or for a non-road diesel-powered engine with a maximum rated capacity less than 900 kW, or for a non-engine emissions source, you may use the appropriate emissions factor from the Compilation of Air Pollutant Emission Factors, Volume 1: Stationary Point and Area Emissions Sources, or VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 any update thereto, incorporated by reference at § 550.198; or, (vii) If you elect to use the methods described in paragraph (b)(2)(v) or (vi) of this section, you must take appropriate account of the deterioration in the performance of the equipment based on its age and the potential variation of the actual emissions from the standard to account for the maximum potential emissions that the emissions source may emit. Given that equipment tends to operate less efficiently over time, you should make an appropriate upward adjustment in the emissions estimates for older equipment. At any time you revise your plan, including resubmissions every ten years, you must consider the age of the equipment, adjust for any change in operating efficiency, and provide the associated emissions factors in your revised or resubmitted plan, as applicable. (3) If the Regional Supervisor has reason to believe that any air emissions factor used in your plan is inappropriate, or new or updated information on emissions factors becomes available, the Regional Supervisor may require you to use a different emissions factor for any emissions source for any air pollutant. The Regional Supervisor may require you to perform stack testing, in accordance with paragraph (b)(1) of this section, or some other form of validation to verify the accuracy of an emissions factor. (4) If you propose to utilize an engine or equipment that is not certified by the USEPA for use in the U.S., you may not use a USEPA emissions factor intended to apply to a certified engine or equipment. If you propose to utilize an engine or equipment that is USEPAcertified, then you must submit documentation of its certification. (5) If your projected emissions include emissions for a U.S. flagged vessel, you must submit documentation of the USEPA-issued Certificate of Conformity for each engine on the vessel. (6) If you propose to use any non-U.S. engine or equipment on a non-U.S. flag vessel that is not MARPOL-compliant, you may not use an emissions factor intended to apply to a MARPOLcompliant engine or equipment. (c) Facility emissions. For each criteria and major precursor air pollutant, calculate the projected annual emissions for each of your facilities, the maximum 12 month rolling sum of facility emissions and the maximum projected peak hourly emissions using the following procedures: PO 00000 Frm 00085 Fmt 4701 Sfmt 4702 19801 (1) Calculate total emissions generated annually by each emissions source on or physically connected to each of the facilities described in your plan that would result from the construction, installation, operation, or decommissioning of the facility. Such calculations should be done for each year that the plan states that the operator proposes to engage in operating activities, up to ten years. This calculation should be based on the maximum rated capacity of each emissions source associated with the facility, or the capacity that generates the highest rate of emissions, and the facility’s maximum potential projected annual emissions, using the methods and procedures specified under paragraphs (a) and (b) of this section. (2) Calculate the maximum 12-month rolling sum of emissions from each emissions source on or physically connected to each facility and the maximum 12-month rolling sum of emissions from each facility that would result from the construction, installation, operation, or decommissioning of the facility. Identify the 12-month period used for this calculation. This should be the 12month period during which your facility generates the highest amount emissions over the life of your plan. (3) Calculate the maximum projected peak hourly emissions from each emissions source on or physically connected to each facility and the maximum projected peak hourly emissions from each facility that would result from the construction, installation, operation, or decommissioning of the facility. (d) Attributed emissions. For each criteria and major precursor air pollutant, calculate the attributed projected annual emissions for each of your MSCs, the maximum 12-month rolling sum of each MSC’s emissions, and the maximum projected peak hourly emissions for each MSC, using the following procedure: (1) For each facility described in your plan, identify the MSCs that will be used to support that facility. To the extent practicable, identify the other facilities that each MSC will support. (2) For each MSC referred to in paragraph (d)(1) of this section: (i) An MSC that is intended to remain at sea continuously (i.e., a vessel that does not typically return to port on a regular basis) should be assumed to operate on a 24-hour basis for any day the MSC operates in the waters overlying the OCS or State submerged lands. (ii) For all other MSCs, calculate the emissions per trip, irrespective of what E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19802 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules other facilities the MSC may also service on each trip. These emissions include all the emissions generated between the time that the MSC leaves its port or home base until it returns (i.e., support emissions per trip). All calculations must be based on the maximum rated capacity or the capacity that generates the highest rate of emissions, if greater, for each emissions source on the MSC. (3) Multiply the emissions per trip from paragraph (d)(2) of this section by the number of trips the MSC will make during the 12 month period described in paragraph (c)(2) of this section to get the total support emissions for that MSC. If the MSC will remain at sea continuously, multiply the emissions it will generate per day by the number of days that it will operate in support of your facility during the 12 month period described in paragraph (c)(2) of this section. (4) If the MSC provides support only to your facility, then you must attribute the MSC’s total support emissions to that facility. (5) For each MSC described in paragraph (d)(1) of this section that supports multiple facilities, you may attribute the total support emissions for that MSC to your facility or you may attribute a portion of its total support emissions to your facility (i.e., calculate the attributed emissions for that MSC) using the following procedure: (i) Subtract the emissions you can document that should be reasonably allocated to other facilities from the total support emissions calculated under paragraph (d)(3) of this section for that MSC; or (ii) If it is not practicable to use the method in paragraph (d)(5)(i) of this section, divide the total support emissions calculated under paragraph (d)(3) of this section by the lowest number of facilities that the MSC will service on a typical trip; or (iii) Where it is not practicable to use either paragraph (d)(5)(i) or (ii) of this section, calculate the greater of: (A) The emissions that would be generated by the MSC traveling roundtrip between the port or home base and the facility; or (B) The emissions generated by the MSC for the entire time it will operate within 25 statute miles of the facility. (6) Calculate the sum of the emissions estimates that result from the calculation in paragraph (d)(4) or (5) of this section for every MSC identified in paragraph (d)(1) of this section. That sum represents the attributed emissions for your facility. (7) All calculations must be based on the maximum rated capacity or the capacity that generates the highest rate VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 of emissions for each of the relevant sources on every MSC. (8) If BOEM questions your determination of the attributed emissions, the Regional Supervisor may require additional documentation to support your findings and may direct you to make changes, as appropriate. (e) Projected emissions. For every facility described in your plan, you must identify the maximum projected emissions for each criteria and major precursor air pollutant by calculating the annual rate (for each calendar year), the maximum 12-month rolling sum, and the maximum peak hourly rate for your facility emissions under paragraph (c)(2) of this section and your attributed emissions under paragraph (d)(6) of this section. (1) If any of your proposed facilities would be located in such a manner as to potentially constitute proximate activities with a pre-existing facility or a facility that was previously approved but not yet constructed, you must identify any such facility in your plan. (2) If you are required to consolidate air emissions from multiple facilities, in accordance with the provisions of § 550.303(d), you must provide the projected emissions information for each facility and provide the complex total emissions for all of the consolidated activities. (f) Emission reduction measure(s) (ERM). You must provide a description of all proposed ERM, including: the affected emissions source(s); the proposed emissions reduction control technologies, procedures and/or operational limits; the emission control efficiencies; the projected quantity of reductions to be achieved; and any monitoring or monitoring system you propose to use to measure or evaluate the associated emissions. You must be able to demonstrate that all ERM meet the requirements of § 550.309. (g) Modeling information. If you are required to conduct any air quality modeling in support of your plan, then you must provide: (1) Table(s) of the appropriate and relevant maximum projected air pollutant concentrations over any area(s) of any State(s), including the most affected attainment area(s) and the most affected non-attainment area(s); (2) Table(s) of the appropriate and relevant maximum projected air pollutant concentrations over any Class I area(s), if relevant; (3) The maximum projected concentrations resulting from the projected emissions for each of your facilities, for each criteria air pollutant and major precursor air pollutant, for the corresponding averaging time(s) PO 00000 Frm 00086 Fmt 4701 Sfmt 4702 (e.g., 1-hour, 3-hour, 8-hour, 24-hour, annual, etc.) specified in the tables in 40 CFR 51.165(b)(2), 40 CFR 52.21(c), and 40 CFR part 50; (4) A list of all inputs, assumptions, and default values used for modeling and justification for each, including the source and justification for the proposed meteorological information; (5) The name and version of the model(s), and whether the model is listed on the USEPA preferred list of models in 40 CFR part 51 appendix W; and (6) A modeling report, including the modeling results. If you have previously provided such a report and/or results of the analysis relevant to paragraphs (e) and (g) of this section to the Regional Supervisor, and the projected emissions are the same as or lower than in the previously submitted report(s) or results, you may instead provide a reference to such report and/or results. (7) For each MSC, provide the distance from each facility described in your plan to the closest relevant home port (for MSCs other than offshore vehicles) or home base (for offshore vehicles), consistent with the maps and information you provide under § 550.224(e) or 550.256(b). (h) Requirements applicable to specific air pollutants—(1) Nitrogen and Sulphur Oxides (NOX and SOX). Various documents cross-referenced by these regulations, refer to NOX and NO2 (nitrogen dioxide) or SOXand SO2 (sulphur dioxide). Whenever possible, you must utilize data or reasonable estimates for NOX and SOX. At a minimum, your projected emissions of NOX must include emissions of nitrogen oxide and NO2, and your projected emissions of SOX must include emissions of SO2. In the event that data on NOX or SOX emissions are not available, you must instead utilize data on nitrogen oxide plus NO2 as a substitute for NOx, and SO2 emissions as a substitute SOX. (2) Particulate Matter (PM10 and PM2.5). For each emissions source, you must provide data and information on both PM10 (PM that is 10 micrometers or less in diameter) and PM2.5 (PM that is 2.5 micrometers or less in diameter) whenever such information is available and evaluate each type of particulate matter (PM) separately under every applicable standard. All reporting of PM2.5 must include the sum of filterable and condensable PM. In the event that data for PM is not separately available for both PM10 and PM2.5 for any given source, you must utilize the PM10 data for the PM10 analysis and the same data for the PM2.5 analysis. A plan that does not contain separate emission E:\FR\FM\05APP2.SGM 05APP2 19803 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules exemption threshold and modeling analysis for each type of PM will not be considered complete. (3) Hydrogen Sulfide (H2S). All emissions of SOX that result from the flaring of hydrogen sulfide must be included in the projected emissions of SOX reported and analyzed as part of your plan, in accordance with the USEPA’s Oil and Natural Gas Sector New Source Performance Standards and National Emission Standards for Hazardous Air Pollutants Reviews. If your projected emissions of H2S will potentially exceed the USEPA’s Significant Emission Rate for H2S, as defined in 40 CFR 51.166(b)(23)(i), you must report the nature and extent of these emissions and their likely impact as part of your plan. (4) Methane (CH4). Unless specifically directed to the contrary by another regulatory provision, the analysis or reporting of CH4 emissions is not required. (5) Ozone (O3). Generally reporting is not required other than in accordance with the provisions of § 550.304(b), unless another regulatory provision specifically addresses O3. (6) Lead (Pb) or Ammonia (NH3). Reporting of emissions for these pollutants, for any given source, is required: if there are published manufacturer specifications of emissions factors for these pollutants; or if such information is available from the USEPA or could be obtained or derived from another recognized source, such as utilizing a mass balance approach. If you intend to use a source known to emit a potentially significant amount of Pb or NH3, then you must obtain a reasonable estimate of the associated Pb or NH3 emissions. Zero emissions for these pollutants should be assumed in the situation where relevant data are not available and neither you nor BOEM have a reason to anticipate that the emissions could be potentially significant. (i) Distance calculations—(1) Distance from shore. For each facility described in your plan, you must calculate and provide the distance in statute miles, as measured in a straight line from the site of the facility to the closer of: (i) The nearest mean high water mark of a State, or, on the Pacific coast, the nearest mean higher high water mark; or (ii) The nearest Class I area of any State. (2) Distance from SSB. For each facility described in your plan, you must calculate and provide the distance in statute miles, as measured in a straight line from the site of the facility to the closest point at which the OCS borders any State, at the SSB. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 (j) Documentation. You must collect, create, and maintain records or any data or information establishing, substantiating, and verifying the basis for all information, data, and resources used to calculate your projected emissions under this section. The emissions factors you propose to use must be documented, and any relevant certifications, citations, methods, and procedures used to obtain or develop emissions factors must be retained. You must collect and maintain all documentation pertaining to the modeling analysis under § 550.205(g), if applicable, including all references and copies of any referenced materials, as well as any data or information related to any ERM that you propose or implement. You must provide this information, unless the Regional Supervisor waives this requirement for good cause. (k) Compliance. You must provide a description of how you will comply with § 550.303 when the emissions generated by your proposed plan activities exceed the respective emission exemption thresholds (EETs), calculated using the formulas in § 550.303(c). If you are subject to the requirement to monitor and report your actual emissions in accordance with § 550.311, then the description you provide must describe how you propose to monitor your emissions. (l) Reporting. You must submit data and information in a format, and using the forms, as specified by BOEM. You must submit information in an electronically-readable format, unless otherwise directed by the Regional Supervisor. If you transmit the information to BOEM electronically, you must use a delivery medium or transmission method authorized by BOEM. (m) Additional information. (1) If you are required to conduct modeling, and if, under § 550.305 your projected emissions would cause an increase in the concentration of any pollutant that is within 95% of any Significant Impact Level (SIL), then you must: Report the amount of emissions from aircraft or onshore support facilities as attributed emissions; and combine the impacts of aircraft and onshore support facilities emissions with the impacts of your projected emissions for the purposes of this section and for your analysis under subpart C of this part. The aircraft and support facilities for which you are required to report emissions are those described in §§ 550.224, 550.225, 550.257, and 550.258. If required to report your aircraft or onshore support facilities and those aircraft or onshore support facilities support multiple OCS PO 00000 Frm 00087 Fmt 4701 Sfmt 4702 facilities then you must allocate their emissions in an appropriate manner similar to that described for MSCs in § 550.205(d). (2) The Regional Supervisor may require such additional data or information related to these sources as is necessary to demonstrate your plan’s compliance with subpart C of this part, and/or applicable federal laws related to the protection of air quality within BOEM jurisdiction. (n) Requirements for plans to be deemed submitted. Your plan will not be deemed submitted in accordance with the requirements of § 550.231 or § 550.266 until: (1) All of the requirements of this section have been completed; (2) You have completed the Ambient Air Increment (AAI) analysis, including the required BOEM forms, the modeling protocol, and the modeling results, as specified in § 550.307(b) if required; and (3) You have completed any other analysis required by subpart C of this part. (o) Plans exempt from review under the AQRP. If you can demonstrate that your facility will not generate projected emissions of any criteria or precursor air pollutant in an amount greater than the corresponding significant emissions rate limit described in the ‘‘Pollutant and Emissions Rate’’ table defined in 40 CFR 52.21((b)(23)(i), your plan is exempt from the AQRP requirements of this section and subpart C of this part. ■ 11. Revise § 550.211(c) to read as follows: § 550.211 What must the EP include? * * * * * (c) Drilling unit. (1) A description of the drilling unit and associated equipment you will use to conduct your proposed exploration activities, including a brief description of its important safety and pollution prevention features, and a table indicating the type and the estimated maximum quantity of fuels, oil, and lubricants that will be stored on the facility. (2) For purposes of this section, the term ‘‘facility’’ means any installation, structure, vessel, vehicle, equipment or device that is temporarily or permanently attached to the seabed of the OCS, including an artificial island used for drilling, well completion, wellworkover, or other operations. * * * * * ■ 12. Revise § 550.212(f) to read as follows: § 550.212 What information must accompany the EP? * E:\FR\FM\05APP2.SGM * * 05APP2 * * 19804 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules asabaliauskas on DSK3SPTVN1PROD with PROPOSALS (f) Air emissions information required by § 550.205; * * * * * ■ 13. Amend § 550.215 by revising paragraph (d)(2) and adding paragraph (e) to read as follows: § 550.241 include? What must the DPP or DOCD * * * * (c) Drilling unit. A description of the drilling unit and associated equipment you will use to conduct your proposed development drilling activities. Include § 550.215 What hydrogen sulfide (H2S) a brief description of its important information must accompany the EP? safety and pollution prevention features, * * * * * and a table indicating the type and the (d) * * * estimated maximum quantity of fuels (2) If any H2S emissions are projected and oil that will be stored on the to affect any location within a State in facility. For the purpose of this section, a concentration greater than 10 parts per the term facility means any installation, million, the modeling analysis must be structure, vessel, vehicle, equipment or consistent with the USEPA risk device that is temporarily or management plan methodologies permanently attached to the seabed of outlined in 40 CFR part 68. the OCS, including an artificial island (e) Hydrogen sulfide. If you propose to used for drilling, well completion, wellflare any gasses containing a potentially workover, or other operations. significant amount of H2S, you must (d) Production facilities. A description separately identify this activity in your of the production platforms, satellite plan and separately identify the structures, subsea wellheads and resulting emissions of sulphur oxides manifolds, lease term pipelines (see (SOX) as part of your projected definition at § 550.105), production emissions under § 550.205(e). facilities, umbilicals, and other facilities you will use to conduct your proposed § 550.218 [Removed and reserved] development and production activities. ■ 14. Remove and reserve § 550.218. Include a brief description of their ■ 15. Revise § 550.224(a) and (b) to read important safety and pollution as follows: prevention features, and a table § 550.224 What information on support indicating the type and the estimated vessels, offshore vehicles, and aircraft you maximum quantity of fuels and oil that will use must accompany the EP? will be stored on the facility. For the * * * * * purpose of this section, the term facility (a) General. A description of the MSCs means a vessel, a structure, or an and aircraft you will use to support your artificial island used for drilling, well exploration activities. The description completion, well-workover, or other of MSCs must estimate the storage operations or used to support capacity of their fuel tanks and the production facilities. frequency of their visits to your facility * * * * * or facilities. ■ 18. Revise § 550.242(g) to read as (b) Air emissions. See § 550.205. follows: * * * * * § 550.242 What information must ■ 16. Revise § 550.225(b) to read as accompany the DPP or DOCD? follows: * * * * * § 550.225 What information on the (g) Air emissions information required onshore support facilities you will use must by § 550.205; accompany the EP? * * * * * * * * * * (b) Air emissions. A description of the ■ 19. Amend § 550.245 by revising paragraph (d)(3) and adding paragraph emissions source, the frequency and (e) to read as follows: duration of its operation, and the types of air pollutants likely to be emitted by § 550.245 What hydrogen sulfide (H2S) the onshore support facilities you will information must accompany the DPP or use. Except as required under DOCD? § 550.205(m), the amount of air * * * * * pollutants emitted need not be reported. (d) * * * You do not need to report this (3) If any H2S emissions are projected information for any onshore support to affect any location within a State in facility if the facility is permitted under a concentration greater than 10 parts per the CAA or if you can identify another million, the modeling analysis must be agency to which this emissions consistent with the USEPA risk information from the facility was management plan methodologies submitted. outlined in 40 CFR part 68. (e) Hydrogen sulfide. If you propose to * * * * * flare any gasses containing a potentially ■ 17. Revise paragraphs § 550.241(c) significant amount of hydrogen sulfide, and (d) to read as follows: VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 * PO 00000 Frm 00088 Fmt 4701 Sfmt 4702 you must separately identify this activity in your plan and separately identify the resulting emissions of SOX, including reporting the sulphur emissions under § 550.205(e). § 550.249 [Removed and reserved] 20. Remove and reserve § 550.249. 21. Revise paragraphs § 550.257(a) and (b) to read as follows: ■ ■ § 550.257 What information on the support vessels, offshore vehicles, and aircraft you will use must accompany the DPP or DOCD? * * * * * (a) General. A description of the MSCs and aircraft you will use to support your activities. The description of MSCs must estimate the storage capacity of their fuel tanks and the frequency of their visits to the facilities you will use to conduct your proposed development and production activities. (b) Air emissions. See § 550.205. * * * * * ■ 22. In § 550.258, revise paragraph (b) to read as follows: § 550.258 What information on the onshore support facilities you will use must accompany the DPP or DOCD? * * * * * (b) Air emissions. A description of the source, the frequency and duration of its operation, and the types of air pollutants likely to be emitted by the onshore support facilities you will use. Except as required under § 550.205(m), the amount of emissions of air pollutants need not be reported. You do not need to report this information for any onshore support facility if the facility is permitted under the CAA or if you can identify another agency to which emissions from the facility was submitted. * * * * * Post-Approval Requirements for an EP, DPP, DOCD, RUE, Pipeline ROW or Lease Term Pipeline Application 23. Revise the undesignated center heading that occurs before § 550.280 to read as set out above. ■ 24. In § 550.280, revise the section heading and the introductory text of paragraph (a) to read as follows: ■ § 550.280 How must I conduct activities under the approved EP, DPP, DOCD, RUE, pipeline ROW, or lease term pipeline application? (a) Compliance. You must conduct all of your lease and unit activities according to your approved EP, DPP, DOCD, or RUE, pipeline ROW, or lease term pipeline application, and any approval conditions. You may not install or use any facility, equipment, E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules vessel, vehicle, or other emissions source not described in your EP, DPP, DOCD, or RUE, pipeline ROW or lease term pipeline application, and you may not install or use a substitute for any emissions source described in your EP, DPP, DOCD, or RUE, pipeline ROW, lease term pipeline application, without BOEM prior approval. If you fail to comply with your approved EP, DPP, DOCD, or RUE, pipeline ROW, or lease term pipeline application: * * * * * ■ 25. In § 550.284, revise the section heading, paragraph (a) introductory text, and (a)(1) to read as follows: § 550.284 How will BOEM require revisions to the approved EP, DPP, DOCD or application for a RUE? (a) Periodic review. The Regional Supervisor will periodically review the activities you conduct under your approved EP, DPP, DOCD, or RUE application and may require you to submit updated information on your activities. The frequency and extent of this review will be based on the significance of any changes in available information, applicable law or regulation, or onshore or offshore conditions affecting, or affected by, the activities in your approved EP, DPP, DOCD, or RUE application. After 2020, any EP, DPP, DOCD or RUE application that was approved more than ten years prior must be resubmitted for air quality review in accordance with the requirements of § 550.310. * * * * * ■ 26. Revise subpart C to read as follows: asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Subpart C—Air Quality Analysis, Control, and Compliance Sec. 550.300 [Reserved] 550.301 Under what circumstances does this subpart apply to operations in my plan? 550.302 Acronyms and definitions concerning air quality. 550.303 What analysis of my projected emissions is required under this subpart? 550.304 What must I do if my projected emissions exceed an emission exemption threshold? 550.305 How do I determine whether my projected emissions of criteria air pollutants require ERM? 550.306 What ERM are required for a shortterm facility? 550.307 What ERM are required for a longterm facility? 550.308 Under what circumstances will BOEM require additional ERM on my proposed facility or facilities? 550.309 What requirements apply to my ERM? VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 550.310 How will revisions to the ambient air quality standards and benchmarks (AAQSB) affect my plan? 550.311 Under what circumstances will I be required to measure and report my actual emissions? 550.312 What post-approval recordkeeping and reporting is required? 550.313 Under what circumstances will BOEM impose additional requirements on facilities operating under already approved plans? 550.314 Under what circumstances will the Regional Supervisor review the projected emissions from my existing facility or facilities? § 550.300 [Reserved] § 550.301 Under what circumstances does this subpart apply to operations in my plan? The provisions of this subpart apply to any existing facility or proposed plan involving a facility or facilities operating on, or proposed to operate on, any area of the OCS where the Secretary of the Interior has authority to regulate air emissions pursuant to section 5(a)(8) of the Outer Continental Shelf Lands Act (OCSLA), 43 U.S.C. 1334(a)(8), as amended, and jurisdiction pursuant to section 328(b) of the CAA, 42 U.S.C. 7627(b), as amended, including OCS operations conducted pursuant to any plan approved under this part. § 550.302 Acronyms and definitions concerning air quality. (a) Acronyms and terms used in this subpart, and in § 550.205, have the following meanings: AAI means ambient air increment(s). AAQSB means ambient air quality standards and benchmarks. AEDT means aviation environmental design tool. APD means application for a permit to drill. AQCR means air quality control region. BACT means best available control technology. BLM means the Bureau of Land Management. Btu IT means British Thermal Unit International Tables. CAA means the Clean Air Act. CEO means Chief Environmental Officer (BOEM) CH4 means methane. CO means carbon monoxide. CP means criteria pollutant. CSU means column-stabilized-units. DOCD means development operations coordination document. DOI means the U.S. Department of the Interior. DPP means development and production plan. ECE means emission control efficiency. EET means emission exemption threshold(s). EIS means environmental impact statement. EP means exploration plan. ERM means emission reductions measure(s). FAA means Federal Aviation Administration. FLM means Federal Land Manager, which includes the heads of the U.S. Bureau of PO 00000 Frm 00089 Fmt 4701 Sfmt 4702 19805 Land Management (BLM), Fish and Wildlife Service (FWS), National Park Service (NPS), Bureau of Land Management (BLM) in DOI and U.S. Forest Service in the Department of Agriculture. FPS means floating production systems. FPSO means floating production storage and offloading vessel. G&G means geological and geophysical. GHG means greenhouse gas. hp means horsepower. hpm means mechanical horsepower. HPU means hydraulic power unit. H2S means hydrogen sulfide. kW means kilowatt. MARPOL means Marine Pollution Convention. MODU means mobile offshore drilling unit. MOVES means motor vehicle emission simulator. MSC means mobile support craft. NAAQS means the primary or secondary national ambient air quality standards. NARA means National Archives and Records Administration. NH3 means ammonia. NO2 means nitrogen dioxide. NOX means nitrogen oxides. O3 means ozone. OCS means Outer Continental Shelf. OCSLA means Outer Continental Shelf Lands Act. ONRR means the Office of Natural Resources Revenue OSFR means oil spill financial responsibility. OSV means offshore supply vessel. Pb means lead. PM means particulate matter. PM2.5 means fine particulate matter equal to or less than 2.5 micrometers in diameter. PM10 means particulate matter equal to or less than 10 micrometers in diameter. PTE means potential to emit. ROW means rights-of-way. Rpm means revolutions per minute. RUE means right-of-use and easement. SILs means significant impact levels. SO2 means sulphur dioxide. SOX means sulphur oxides. SSB means State seaward boundary TAS means treatment as State. TIP means tribal implementation plan. TLP means tension-leg platforms. VOC means volatile organic compound. U.S. means the United States. USEPA means the United States Environmental Protection Agency. mg/m3 means micrograms per cubic meter. (b) Terms used in this subpart have the following meanings: Air quality control region (AQCR) means an interstate area or major intrastate area, which the USEPA deems appropriate for assessing the regional attainment and maintenance of the primary or secondary national ambient air quality standards described in 42 U.S.C. 7409, as provided under 40 CFR part 81, subpart B, Designation of Air Quality Control Regions. Ambient Air Increments (AAIs) means the national benchmarks for Ambient Air Increments set out in the table in 40 CFR 52.21(c), as amended, or in 42 U.S.C. 7473 et seq., as amended. E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19806 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Ambient air quality standards and benchmarks (AAQSB) means any or all of the national ambient air quality standards and benchmarks referenced in this subpart, including the primary and secondary NAAQS defined in 40 CFR part 50; the SILs, in 40 CFR 51.165(b)(2); the AAIs, as set out in the table in 40 CFR 52.21(c). Attainment area means, for any given criteria air pollutant, a geographic area, which is not designated by the USEPA as being a designated non-attainment area, as codified at 40 CFR part 81 subpart C (40 CFR 81.300 through 81.356). This includes areas that are referred to as attainment, maintenance, unclassifiable, or unclassifiable/ attainment in that subpart, as well as areas that have not yet been designated because the two-year period to complete such designations after revision of a NAAQS has not yet passed. Attributed emissions means, for any given criteria or precursor air pollutant, the emissions from MSC and, if appropriate, aircraft, operating above the OCS or State submerged lands, that are attributed to a facility pursuant to the methodology set forth in § 550.205(d) for the period over which the corresponding facility emissions are measured. Background concentration means the ambient air concentration of any given criteria air pollutant that arises both from local natural processes and from the transport into the airshed of natural or anthropogenic pollutants originating locally or from another location, either as measured from an USEPA-approved air monitoring system or as determined on some other appropriate scientifically justified basis approved by BOEM. Baseline concentration means the ambient background concentration of any given air pollutant that exists or existed at the time of the first application for a USEPA Prevention of Significant Deterioration (PSD) permit in an area subject to section 169 of the CAA, based on air quality data available to the USEPA or a State air pollution control agency and on the monitoring data provided in the permit application and as defined in 40 CFR 51.166(b)(13). The baseline concentration is distinguished from the background concentration in that the background concentration changes continually over time to reflect the current ambient air concentration for any given air pollutant, whereas the baseline concentration remains fixed until such time as a new AAI is established for an attainment area. Best Available Control Technology (BACT) means a physical or mechanical system or device that reduces emissions VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 of air pollutants subject to regulation to the maximum extent practicable, taking into account: The amount of emissions reductions necessary to meet specific regulatory provisions; energy, environmental, and economic impacts; and costs. Class I area means an area designated by the USEPA, a State, or a Federallyrecognized Indian tribe, where visibility and air emissions are protected by a FLM to pursuant to 42 U.S.C. 7472(a) or 7474, as amended; Class I areas include certain national parks, wilderness areas, national monuments, and areas of special national or regional natural, recreational, scenic, or historic value. Class II area means an area designated by the USEPA, a State, or a Federallyrecognized Indian tribe, that is protected pursuant to 42 U.S.C. 7472(a) or 7474, as amended, to limits less stringent than those for Class I areas. Sensitive Class II areas represent a sub-classification of Class II areas that are defined by Federal Land Management Agencies as federal lands where the protection of air resources has been prioritized, as specified in acts, regulations, planning documents, or by policy. Complex total emissions means the sum of the facility emissions that would result from all of the facilities that have been aggregated for the purposes of evaluating their potential consolidated impact on air quality, pursuant to the methodology set forth in § 550.303(d), and the sum of all corresponding attributed emissions for those facilities. Criteria air pollutant or criteria pollutant means any one of the principal pollutants for which the USEPA has established and maintains a NAAQS under 40 CFR part 50 in accordance with 42 U.S.C. 7409, as amended, for the protection of public health and welfare, and the environment. The USEPA has established primary standards for the protection of sensitive populations of children and the elderly and secondary standards for the protection of crops, vegetation, buildings, visibility, and prevention of harm to animals. Criteria air pollutants do not include Volatile Organic Compounds (VOCs) or any other precursor air pollutant not already regulated under the NAAQS. Design concentration means the pollutant concentration at a given location projected, through computersimulated air dispersion or photochemical modeling, as described under 40 CFR part 51, appendix W, section 7.2.1.1 to result from your projected emissions, combined with the background concentration for the same pollutant, averaging time, and statistical form at the most appropriate receptor PO 00000 Frm 00090 Fmt 4701 Sfmt 4702 location. The appropriate background concentration is measured from the nearest point at which there is data from an USEPA-approved air monitoring system, or as determined on some other appropriate scientifically justified basis approved by BOEM. Dispersion modeling means the mathematical computer simulation of air emissions being transported from a source through the atmosphere under given meteorological conditions. Emissions from sources, expressed as the rate of air pollutants emitted over time (i.e., pounds per hour), are translated through computer modeling into pollutant concentrations, expressed in units of micrograms of pollutants per cubic meter of ambient air (mg/m3), or in parts per million or billion, depending on the circumstances. When a file containing meteorological and emissions data are input into the computer model, the model will project the concentrations of the pollutants at a receptor location. Emission control efficiency (ECE) means the effectiveness of an ERM for any given emissions source and air pollutant. The greater the emission control efficiency, the greater the effectiveness of the underlying controls (i.e., measured as a percentage reduction in the underlying emissions of any given pollutant). ECE varies from 100%, representing a control that completely eliminates emissions, to zero, representing a control that has no effect on such emissions. Emissions credits mean emissions reductions from an emissions source(s) not associated with the plan that are intended to compensate for the excessive emissions of criteria or precursor air pollutants, regardless of whether these emissions credits are acquired from an emissions source(s) located either offshore or onshore, including: Emissions offsets generated by the lessee or operator itself; or emissions offsets acquired from a third party; or trading allowances or other alternative emission reduction method(s) or system(s) associated with a market-based trading mechanism; examples include mitigation banks or other competitive markets where these assets are exchanged. Emission exemption threshold(s) (EET) means the maximum allowable rate of projected emissions, calculated for each air pollutant, expressed as short tons per year (tpy), above which facilities would be subject to the requirement to perform modeling. Emissions factor(s) means a value that relates the quantity of a specific pollutant released into the atmosphere with the operation of a particular E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules emissions source. Emissions factors are usually expressed as the mass of pollutant generated from each unit (e.g., mass, volume, distance, work, or duration) of activity by the emissions source emitting the pollutant. Emission reduction measure(s) (ERM) means any operational control(s), equipment replacement(s), BACT, or emissions credit(s), applied on either a temporary or permanent basis, to reduce the amount of emissions of criteria or precursor air pollutants that would occur in the absence of such measures. Existing facility means an operational OCS facility described in an approved plan. Facility means, any installation, structure, vessel, vehicle, equipment, or device that is temporarily or permanently attached to the seabed of the OCS, including but not limited to a dynamically positioned ship, gravitybased structure, manmade island, or bottom-sitting structure, whether used for the exploration, development, production or transportation of oil, gas, or sulphur. All installations, structures, vessels, vehicles, equipment, or devices directly associated with the construction, installation, and implementation of a facility are part of a facility while located at the same site, attached, or interconnected by one or more bridges or walkways, or while dependent on, or affecting the processes of, the facility, including any ROV attached to the facility. One facility may include multiple drill rigs, drilling units, vessels, platforms, installations, devices, and pieces of equipment. Facilities include Mobile Offshore Drilling Unit(s) (MODU), even while operating in the ‘‘tender assist’’ mode (i.e., with skid-off drilling units), or any other vessel engaged in drilling or downhole operations, including wellstimulation vessels. Facilities also include all Floating Production Systems (FPSs), including Column-StabilizedUnits (CSUs), Floating Production, Storage and Offloading facilities (FPSOs), Tension-Leg Platforms (TLPs), and spars. Any vessel used to transfer production from an offshore facility is part of the facility while physically attached to it. Facilities also include all DOI-regulated pipelines and any installation, structure, vessel, equipment, or device connected to such a pipeline, whether temporarily or permanently, while so connected. Facility emissions means, for any given criteria or precursor air pollutant, the annual, the maximum 12-month rolling sum, and the peak hourly emissions from all emissions sources on or connected to a facility. VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Federally-recognized Indian tribe refers to a Federally-recognized Indian tribe that has either a Treatment as State (TAS) status recognized by the USEPA or an approved TIP. Fugitive emissions means the emissions of an air pollutant from an emissions source that do not pass through a stack, chimney, vent, or other functionally-equivalent opening. Fully reduce(d) means to decrease emissions of VOCs to a rate that will not exceed the emission exemption threshold calculated under § 550.302, or to decrease emissions of criteria air pollutants to a rate that will not exceed the Significant Impact Levels set out in the table in 40 CFR 51.165(b)(2). Long-term facility means a facility that has remained or is intended to remain in the same lease block or within one nautical mile of its original location for three years or longer; this three year period is measured from the time the facility is first attached to the seafloor, or another facility, and continues to run until the facility’s planned operations cease, regardless of the length of time the facility remains attached to the seafloor in any given year. Major precursor pollutant means any precursor pollutant for which the States are required to report actual emissions to the USEPA, as defined in 40 CFR 51.15(a). MARPOL-certified engine means either: (1) An engine with a power output of more than 5,000 kW and a per cylinder displacement at or above 90 liters installed on a ship constructed on or after January 1, 1990 but prior to January 1, 2000 that is subject to regulation 13.7 of MARPOL Annex VI; or (2) An engine with a power output of more than 130 kW built on or after January 1, 2000 that is subject to regulations 13.1 through 13.6 of MARPOL Annex VI. Maximum rated capacity means the maximum power an engine is capable of generating over time, expressed in kW, and if necessary, as converted from hpm (where 1 hpm of power equals 745.699872 Watts or 0.745699872 kW) or from the International Table values of British thermal units (BtuIT, where 1 BtuIT/hour of power equals 0.29307107 Watts or 0.00029307107 kW). National ambient air quality standards (NAAQS) means the ambient air standards established by the USEPA, as mandated by the CAA (42 U.S.C. 7409), set out in in 40 CFR part 50, for the common criteria air pollutants considered harmful to public health or welfare. There are two categories of the NAAQS: Primary standards that set PO 00000 Frm 00091 Fmt 4701 Sfmt 4702 19807 limits to protect public health, including the health of ‘‘sensitive’’ populations such as asthmatics, children, and the elderly; and secondary standards that set limits to protect public welfare when concentrations are elevated over time, including protection against visibility impairment; prevention of harm to animals, including marine mammals, fish and other wildlife; and avoidance of damage to crops, vegetation, and buildings. This term includes both categories. Non-attainment area means, for any given criteria air pollutant, a geographic area, which the Administrator of the USEPA has designated as nonattainment for a NAAQS, as codified at 40 CFR part 81 subpart C. For the purposes of these regulations, all other areas will be considered Attainment areas. Operational control means a process, method or technique, other than a physical or mechanical control, or equipment replacement that reduces the emissions of criteria or precursor air pollutants (e.g., limitation on period of operation, load balancing, and/or use of less-polluting fuels). Particulate matter (PM) means an airborne contaminant of particulate matter that is regulated as a criteria air pollutant under the ambient air standards. PM10 refers to airborne contaminants of particulates less than or equal to 10 micrometers. PM2.5, or fine PM, is an airborne contaminant composed of particulates less than or equal to a diameter of 2.5 micrometers. Plan means any initial, revised, modified, resubmitted, or supplemental Exploration Plan (EP), Development and Production Plan (DPP), Development Operations Coordination Document (DOCD), or application for a Right-ofUse and Easement (RUE), a Pipeline ROW, or a lease term pipeline application. Potential to emit (PTE) means the maximum capacity of a source to emit a pollutant under its physical and operational design. Any physical or operational limitation on the capacity of the source to emit a pollutant, including air pollution control equipment and restrictions on hours of operation or on the type or amount of material combusted, stored, or processed, will be treated as part of its design if the limitation or the effect it would have on emissions is federally enforceable. Attributed emissions are not counted in determining a facility’s PTE. Precursor air pollutant or precursor pollutant means a compound that chemically reacts with other atmospheric gases to form a criteria air pollutant. Some precursor air pollutants E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19808 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules are also defined as criteria air pollutants. Precursor air pollutants include VOCs, NOX, SOX, and NH3. Projected emissions means, for any given criteria or precursor air pollutant, the sum of facility’s (or facilities’) emissions and the corresponding attributed emissions over the specified time period, with the controlled or uncontrolled nature of the pollutants specified by the context. Proximate activities means activities that involve or affect any of the following: The same well(s); a common oil, gas, or sulphur reservoir; the same or adjacent lease block(s); or, facilities located within one nautical mile of one another. Where a well is drilled from one facility, but production from that well will ultimately take place through a different facility, the drilling and production activities constitute proximate activities if they occur within the same twelve months. Sensitive Class II area means a Class II area defined by an FLM agency as being federal land where protection of air resources has been prioritized, as specified in acts, regulations, planning documents, or policy. Short-term facility means any facility that is not a long-term facility or connected to a long-term facility. Significance level or Significant impact level (SIL) means an ambient air benchmark or limit that applies to the ambient air impact of the emissions of a criteria air pollutant, as set out in the table in 40 CFR 51.165(b)(2). Technically feasible means a technology or methodology that: Has been demonstrated to operate successfully on the same type of emissions source as the one under review; or is available and applicable to the type of emissions source under review. Total support emissions means, for any criteria or precursor air pollutant, the total emissions generated by an MSC that operates in support of your and any other facilities, for the 12-month period over which the corresponding facility emissions are measured. For example, for any given MSC, the total support emissions would equal the number of service trips (i.e., from the port to the supported facilities) made during the relevant 12-month period multiplied by the average number of hours per service trip multiplied by the emissions per hour for all emissions source(s) on that MSC (derived from the emissions factor calculation). § 550.303 What analysis of my projected emissions is required under this subpart? (a) Establishing emission exemption thresholds. BOEM establishes the rate of VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 projected emissions, calculated for each air pollutant, above which facilities would be subject to the requirement to perform modeling. These EETs establish those rates of emissions below which BOEM has determined emissions would not significantly affect the air quality of any State. If your projected emissions or complex total emissions are exempt, then you will not be required to perform air quality modeling in accordance with the requirements of § 550.304 and to apply any controls, as described in §§ 550.305 through 550.307. (b) Calculating projected emissions. You must compare your projected emissions, or your complex total emissions if you are required to consolidate multiple facilities under paragraph (d) of this section, with the EETs, pursuant to the following methodology: (1) Projected emissions. You must calculate and report the projected emissions for each facility as set forth in § 550.205(e). (2) Attributed emissions. You must calculate and report all attributed emissions for each facility as set forth in § 550.205(d). (c) Exempt emissions thresholds. BOEM will establish EETs under this paragraph. These will determine whether your projected emissions or complex total emissions have the potential to significantly affect the air quality of any State. (1) BOEM will establish new EETs based on the factors listed in this paragraph and publish them in the Federal Register. BOEM may establish different EETs that apply to different areas of the OCS or that apply to different kinds of emissions sources. BOEM may establish different EETs that apply to different areas of the OCS or that apply to different kinds of emissions sources. If your projected emissions for any criteria air pollutant or precursor air pollutant exceeds an EET, then you will be required to perform air quality modeling in accordance with the requirements of § 550.304 and you may be required to apply controls, as described in §§ 550.305 through 550.307, unless scientific evidence and the application of the factors set in paragraph (c)(2) of this section demonstrates otherwise. (i) The first time that BOEM establishes a new set of EETs, BOEM will publish a notice in the Federal Register describing the proposed EETs and will specify the length of a corresponding comment period. At the conclusion of the comment period, BOEM will review and evaluate the comments and make a determination as to the final EETs. BOEM will publish a PO 00000 Frm 00092 Fmt 4701 Sfmt 4702 subsequent notice in the Federal Register listing the new EETs, along with a corresponding effective date for the new EETs. (ii) Any time that BOEM determines that a revised EET should be established, BOEM will publish a notice in the Federal Register describing the proposed revised EET and will specify the length of a corresponding comment period. At the conclusion of the comment period, BOEM will review and evaluate the comments and make a determination as to the final EET. BOEM will publish a subsequent notice in the Federal Register listing revised EET, along with a corresponding effective date for the revised EET. (iii) Until the date of the notice described in paragraph (c)(1)(ii) of this section, a facility will not be exempt under this section if its projected emissions of any pollutant exceed EETs as calculated using the following formulas: (A) EET = 3400 × D2/3 for emissions of carbon monoxide (CO); and (B) EET = 33.3 × D for emissions of each of the following: Nitrogen oxides (NOX); SOX; volatile organic compounds (VOCs); and PM10. Where D is the distance of the facility from the shoreline, as identified in § 550.205(i)(1). (C) For Pb, the EET value is the level defined in 40 CFR 52.21(b)(23)(i). (iv) Subsequent to the date of the notice, a facility will not be exempt under this section if its projected emission of any pollutant exceeds an EET published in the notice. (v) Because the USEPA’s AAQSB are subject to change as scientific knowledge improves and because modeling and evaluation techniques may improve over time, BOEM will revise EETs on an ongoing basis. Thus, as the USEPA revises the NAAQS, or any applicable SIL or AAI, BOEM, at its discretion, will periodically revise its EET formula(s) or its amount(s) for the corresponding air pollutant(s), as appropriate. (2) BOEM will determine new EET formulas taking into account the following factors: (i) The absolute level of projected emissions; (ii) The distance of the proposed facility or facilities from any State or from areas critical to natural resources, animals, and habitats; (iii) The existing ambient air pollution in potentially affected States, trend in the ambient air pollution in those States, the associated attainment status of such areas, and the associated effects to public health and welfare; E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules (iv) Any USEPA AAQSB applied in this part; (v) The types, frequency, and duration of any air pollutant emissions and their formation and/or dispersion characteristics; (vi) The characteristics of the facility or facilities and MSCs, including the type and nature of the emissions sources, and the height of the associated points or stacks; (vii) Prevailing meteorological characteristics in any given area, including air stability, relevant wind speeds and directions; (viii) The amount of emissions from existing facilities and vessels in the vicinity of the proposed facility; and (ix) Other necessary and appropriate considerations. (3) BOEM will set the EET formulas within the following ranges: (i) The minimum values in this range are determined by the formulas in table 1 to § 550.303. TABLE 1 TO § 550.303 Minimum value equation Pollutant * and averaging period Emin = 0.677(d 1.2693) Annual NOX, SOX, and PM10. Emin = 0.2031(d 1.2693) Annual PM2.5. Emin = 3.3851(d 1.2693) 24-hr SO2 and PM10. Emin = 0.8124(d 1.2693) 24-hr PM2.5. Emin = 1354(d 1.2693) .. 1-hr CO. Emin = 338.51(d 1.2693) 8-hr CO. Emin = 16.926(d 1.2693) 3-hr SO2. Where d is the distance in statute miles from the State seaward boundary, as reported in your plan under § 550.205(i)(2) and Emin equals tons per year. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS * For Pb, the minimum value amount is the level defined in 40 CFR 52.21(b)(23)(i). (ii) The maximum values of this range are set by the following formulas: (A) If d ≤ 3, then Emax = 7072 for CO; and Emax = 100 for NOX, SOX, VOCs, and PM10. (B) If d > 3, then Emax = 3400 × d2/3 for CO; and Emax = 33.3 × d for NOX, SOX, VOCs, and PM10. Where d will be the distance of the facility from the SSB as identified in § 550.205(i)(2). (4) If your projected emissions for any criteria air pollutant or precursor air pollutant exceeds the EETs as determined pursuant to § 550.303, then you will be required to perform air quality modeling in accordance with the requirements of § 550.304 and you may be required to apply controls, as described in §§ 550.305 through 550.307. (d) Consolidation of air pollutant emissions from multiple facilities. (1) You must report the projected emissions VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 from multiple facilities which may have been or are described in multiple plans, as the complex total emissions for your plan, if: (i) The air pollutant emissions are generated by proximate activities (i.e., the same well(s); a common oil, gas, or sulphur reservoir; the same or adjacent lease block(s); or, by facilities located within one nautical mile of one another); and (ii) You wholly or partially own, control or operate those facilities; in the event of a dispute as to what constitutes common ownership, control or operations, BOEM will make a determination by reference to the ONRR criteria defined in 30 CFR 1206.101 and 1206.151; and (iii) The construction, installation, drilling, operation, or decommissioning of any of your facilities occurs within a contemporaneous 12-month period as the construction, installation, drilling operation, or decommissioning of any other facility; and (iv) Such a consolidation of emissions from multiple facilities would generate emissions sufficient to exceed an applicable emission exemption threshold (based on the exemption review described in paragraphs (e) or (f) of this section). (2) If any two or more facilities meet all of the conditions specified in (d)(1)(i) through (iii) of this section, you must calculate the sum of the projected emissions from those facilities (including their respective attributed emissions) as the complex total emissions for your plan. (3) BOEM will make a determination that you have appropriately considered the relevant data in your analysis of the complex total emissions. (4) If you are required to consolidate projected emissions data from multiple facilities, then anywhere a requirement applies to projected emissions you must instead use complex total emissions, except with respect to the process by which projected emissions are determined for any given facility (as specified in § 550.205(d)). (e) Emissions do not exceed any threshold. If none of your projected emissions or complex total emissions of any precursor or criteria air pollutant exceeds the applicable emission exemption threshold, then your projected emissions are de minimis, and no further analysis is required under this subpart. (f) Emissions exceed a threshold. If your projected emissions or complex total emissions of the precursor or criteria air pollutant exceed the applicable emission exemption threshold, then further review and/or PO 00000 Frm 00093 Fmt 4701 Sfmt 4702 19809 controls are required, in accordance with the provisions below: (1) If the exceedance is for VOCs, you must control your emissions of VOCs in accordance with § 550.306, for a shortterm facility, or § 550.307, for a longterm facility. (2) If the exceedance is for any criteria air pollutant, then you must conduct modeling in accordance with § 550.304. (3) If the exceedance is for NOX, VOCs, or CO, and if the conditions specified in § 550.304(b) have been met, you are required to conduct photochemical modeling for O3. (4) If the exceedance is for NOX, VOCs, PM2.5, or SOX, and if the conditions specified in § 550.304(b) have been met, you are required to conduct photochemical modeling for PM2.5. (g) Changes to previously approved plans. (1) If you change your plan implementation, such that your projected emissions, or your complex total emissions, will occur in years other than those that were previously approved, you must submit a revised plan, and that revised plan must be approved before you implement the proposed changes. (2) If at any time you anticipate an increase in the maximum air pollutant emissions from a previously approved plan, you must submit a revised plan, pursuant to 30 CFR 550.283(a)(4). (3) If you propose to make a change to your operations on your existing facility or facilities, but not to the equipment used in such operations, and your approved projected annual emissions in any given year are higher than those previously approved for the particular year, but lower than the maximum air pollutant emissions for any year, you do not need to submit a revised plan—as long as the operations would occur in the same year as described in the previous plan. (4) If you propose to make a change to the equipment on your existing facility or facilities in a year or years where your plan already anticipated operations, and your proposed change would result in an increase in air pollutant emissions from that equipment for any air pollutant, you must submit a revised plan. (5) If your plan was approved for a short-term facility that becomes a longterm facility, then you must submit a revised plan for review and approval by BOEM. (h) Federal land manager. If BOEM believes that your proposed activities may affect a Class I or a Sensitive Class II area of a State: (1) BOEM may consult with one or more relevant FLMs to determine what E:\FR\FM\05APP2.SGM 05APP2 19810 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules effects could result from your proposed activities. (2) BOEM will consider the views of the FLMs in determining whether your plan complies with the provisions of this subpart. Based on this consultation, BOEM may require additional information and analysis, either prior to or as a condition of approving your plan. (3) If the FLM does not raise any concerns regarding your plan in a timely manner, BOEM will assume that the FLM has no objections to the proposed plan. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS § 550.304 What must I do if my projected emissions exceed an emission exemption threshold? If your projected emissions or your complex total emissions exceed the limits defined in § 550.303(c) for any criteria or precursor pollutant, you must conduct modeling of that pollutant, and any other pollutant for which that pollutant is a precursor, to project the impacts of those emissions. (a) Dispersion models. (1) You must use one or more of the following air dispersion models: (i) A model approved by the USEPA, as described in appendix A to appendix W of 40 CFR part 51 (Summaries of Preferred Air Quality Models); or (ii) A model included in the Federal Land Managers’ Air Quality Related Values Workgroup Guidance; or (iii) Another model approved by the BOEM Chief Environmental Officer (CEO). (iv) The BOEM CEO may disapprove the use of a USEPA-approved or FLMapproved air quality model, if the CEO determines that such model would not be appropriate in the OCS context. (2) You must follow the modeling procedures recommended in 40 CFR part 51 appendix W, to the extent possible. You must provide BOEM with a copy of your dispersion modeling protocol and the associated data and assumptions used to do your analysis before you conduct modeling. (b) Photochemical models. Photochemical modeling is required only if: (1) Your projected emissions (or your complex total emissions where applicable) for the relevant precursor air pollutants exceed an applicable EET; (2) An appropriate photochemical air quality model is available that: (i) Meets the USEPA’s requirements of section 3.2 of appendix W to 40 CFR; (ii) Complies with the Federal Land Managers’ Air Quality Related Values Workgroup Guidance; or (iii) Is another model approved by the BOEM CEO; VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 (3) BOEM has determined that adequate relevant information on background concentrations is available for the relevant location(s) in a potentially affected State(s). (4) Upon request, you must provide BOEM with a copy of your photochemical modeling protocol and the associated data and assumptions used to do your photochemical analysis before you conduct modeling. (c) Projected emissions. Base your modeling on the maximum projected emissions, as reported under § 550.205(e), or on the complex total emissions, where applicable; (d) Meteorology. Apply the best available and most recent meteorological dataset, either as directed in 40 CFR part 51 appendix W, or by using an alternate dataset approved by the Regional Supervisor. (e) Estimates of ambient air concentrations. For each criteria air pollutant resulting from your projected emissions (or complex total emissions where applicable), estimate the peak incremental concentrations projected in any attainment area(s) and, separately, in any non-attainment area(s), in any State (over State submerged lands or onshore), both on an annual basis and for the other averaging times specified in the appropriate USEPA regulations at 40 CFR part 50 and the tables at 40 CFR 51.165(b)(2) and 40 CFR 52.21(c). (1) To the extent practicable, your estimate of the incremental ambient air concentrations of any criteria air pollutant must consider not only the dispersion of each criteria air pollutant itself, but also the formation of any criteria air pollutant that may result from the dispersion or presence of any relevant precursor air pollutant(s). Specifically: (i) Any analysis of PM2.5 must include NOX, SOX, VOCs, and NH3 (ii) Any analysis of O3 must include NOX, VOCs, and CO. (2) BOEM may provide information though a Notice to Lessees to assist lessees and operators in evaluating existing ambient air concentrations, or changes in such concentrations over time if it determines that there is an effective means of estimating ambient air quality. (i) In the event that BOEM has established appropriate background concentration data, or baseline concentration data, for any given pollutant, at any given location and point in time, you must use the data provided by BOEM. (ii) In the event that BOEM has not established appropriate background concentration data for any given pollutant, for any given location, and PO 00000 Frm 00094 Fmt 4701 Sfmt 4702 point in time, you should use the relevant data from the USEPA for the closest appropriate location, as specified by the Regional Supervisor. (f) Attributed emissions. Conduct modeling of attributed emissions from those locations where the emissions are expected to occur (i.e., utilizing a line, area, volume, or pseudo point source model). (g) Documentation and reporting. Create a modeling report documenting all emissions sources, inputs, parameters, assumptions, procedures, methods, and results, including input and output files, and data upon which your analysis under this subpart is based, and provide BOEM with this report, copies of all data and access to any programs used in your modeling. § 550.305 How do I determine whether my projected emissions of criteria air pollutants require ERM? (a) For all criteria air pollutants other than PM2.5 and O3, compare the results of the modeling described in § 550.304 with the SILs set out in the table at 40 CFR 51.165(b)(2). If the modeling results exceed a SIL for any criteria air pollutant for any averaging time, you are required to apply ERM to sources to reduce emissions only for the CPs that exceed a SIL, as specified in § 550.306 for a short-term facility, or as specified in § 550.307 for a long-term facility. (b) For PM2.5, you must add the results of your dispersion modeling of direct PM2.5 emissions conducted under § 550.304(a) to the results of your photochemical modeling, if required under § 550.304(b), before you compare the results with the PM2.5 SILs set out in the table at 40 CFR 51.165(b)(2). If this sum exceeds a SIL for PM2.5 for any averaging time, you are required to apply ERM for a short-term facility as specified in § 550.306, or as specified in § 550.307, for a long-term facility. (c) For O3, you must add the results of your photochemical modeling, if required under § 550.304(b), to the existing background concentrations, as described under § 550.302, and determine if the sum exceeds the NAAQS for O3 for any averaging time. If so, for a short-term facility, you must apply ERM as specified in § 550.306, or as specified in § 550.307 for a long-term facility. § 550.306 What ERM are required for a short-term facility? (a) If any short-term facility requires ERM under § 550.303(f) for VOCs or § 550.305 for a CP, then you are required to conduct an ERM analysis to determine potential control options and their likely cost effectiveness. In E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules conducting your ERM analysis, you must: (1) Identify all available control technologies relevant to the emissions of the pollutant(s) for which ERM is required; (2) Determine which of these options are technically feasible for your plan; a demonstration of technical infeasibility must be clearly documented and must show, based on physical, chemical or engineering principles, that technical difficulties would preclude the successful use of the applicable emission control technology or methodology. (3) Rank the technically feasible control technologies by their emission control efficiencies (ECE) and determine their likely reduction of criteria air pollutant emissions (i.e., absolute effectiveness), in tpy of emissions avoided; (4) Evaluate the most effective ERM and document the results of your analysis; and (5) Select reasonable operational controls or replacement(s) of equipment that are technically and economically feasible and that are designed to limit your facility’s projected emissions to the greatest practicable extent, taking into consideration the effectiveness and the cost of implementation, for each option considered. You must demonstrate that you have chosen the most effective technically and economically feasible operational controls or replacement(s) of equipment for every pollutant requiring such controls that can be implemented cost effectively. As an alternative, you may propose an equivalent reduction through the use of emissions credits. (6) If you can demonstrate to the satisfaction of the Regional Supervisor that no technically feasible operational controls or equipment replacement(s) can be implemented cost effectively, then; (i) For any given pollutant, if your emissions would affect only attainment areas, no ERM will be required with respect to that pollutant beyond that which was proposed in your plan. (ii) If your emissions affect any nonattainment area for a specific pollutant, the Regional Supervisor may require the implementation of other ERM for that pollutant in lieu of operational controls or equipment replacement(s) as a condition of approving your plan. For any proposed BACT, you must provide a description of the associated energy, environmental, and economic impacts, and other costs. (b) Unless you demonstrate to the satisfaction of the Regional Supervisor that no technically feasible control VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 technology can be implemented cost effectively, your plan must include: (1) An evaluation of the ERM you select, quantifying and verifying the emission reduction measure(s) and associated cost(s); (2) A description of how your selected operational controls or replacement(s) of equipment meet the criteria in § 550.309 for emission reduction measures; and a calculation of your revised projected emissions (or complex total emissions, where applicable), taking into account your selected operational controls or replacement(s) of equipment. (c) Upon making a commitment to apply the appropriate operational controls or replacement(s) of equipment or other ERM in lieu of operational controls or replacement(s) of equipment, BOEM may approve your plan, provided all other applicable requirements have been met. (d) In the event that BOEM obtains information or data that would indicate that your projected emissions may cause the NAAQS to be exceeded, the Regional Supervisor may require you to provide additional data, analysis, or modeling to demonstrate compliance with the NAAQS or may require that you implement additional ERM so that the NAAQS are not exceeded. § 550.307 What ERM are required for a long-term facility? (a) Control of emissions of VOCs from a long-term facility. If any long-term facility requires ERM for VOCs under § 550.303(f), you must propose ERM for the facility. The extent of the ERM required depends on the attainment status of the State area affected by your projected emissions. (1) Except as provided in paragraph (3), if all the State areas potentially affected by your projected emissions of VOCs are designated as attainment areas for O3 and PM2.5, then you must evaluate and propose ERM utilizing the process described for a short-term facility in § 550.306(a)(1) through (4) and consider all relevant ERM, excluding BACT. You must demonstrate in your plan that the ERM you propose, excluding BACT, will reduce the emissions of VOCs to the lowest practicable and reasonable rate, expressed in tpy. If you elect to propose BACT in lieu of an alternative ERM, you must provide a description of the associated energy, environmental, and economic impacts, and other costs. (2) Except as provided in paragraph (a)(3) of this section, if your projected emissions of VOCs potentially affect a State coastal area designated as a nonattainment area for O3 or PM2.5, then you must evaluate BACT and other PO 00000 Frm 00095 Fmt 4701 Sfmt 4702 19811 relevant ERM and propose ERM utilizing the process described for a short-term facility in § 550.306(a)(1) through (4). You must fully reduce the projected emissions of VOCs to a level not to exceed the EET for VOCs, as calculated for your plan in accordance with § 550.303(c). If your proposed ERM are insufficient to reduce the emissions of VOCs to a level that does not exceed the EET, you must propose and apply additional ERM until such reduction is achieved. For any proposed BACT, you must provide a description of the associated energy, environmental and economic impacts, and other costs. (3) VOC waiver: If your projected emissions of VOCs potentially affect a State coastal area but you can demonstrate that your VOCs will not cause an increase, or would cause a reduction, in the formation of O3 (i.e., reduce the O3 production efficiency), then no ERM are required for those VOCs. (b) Control of emissions of criteria air pollutants from a long-term facility. If a long-term facility requires ERM for criteria air pollutants under § 550.305, then you must propose ERM and conduct modeling as specified below. The objectives of your proposal, and the extent to which additional requirements may apply, depend on the attainment status of the affected State area(s). (1) If all State areas affected by your emissions are designated as attainment areas, then: (i) You must consider all relevant ERM excluding BACT, utilizing the process described for a short-term facility in § 550.306(a)(1) through (4). (ii) You must conduct modeling for all of the air pollutants set out in the table at 40 CFR 52.21(c) using the reduced projected emissions that result from your proposed ERM. If photochemical models are required under § 550.304, then you must also perform photochemical modeling and add the results of those models to the results of the subsequent model results. (iii) You must combine the ambient air concentrations resulting from the projected emissions of each relevant CP with those emissions of the same CP from other onshore and offshore sources which contribute to the consumption of the maximum allowable increases above the baseline concentration for each pollutant and baseline area as established in 40 CFR 52.21. Compare your results with the AAIs applicable to the Class area designation of the State area set out in table 40 CFR 52.21(c). (A) For this analysis, use the ambient air quality concentration data specified in § 550.304(e)(2). E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS 19812 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules (B) As an alternative, you may instead model only the increment-related emissions increases and decreases between the baseline date and the modeling date (using emissions inventory data) for all relevant onshore and offshore sources, combined, and then compare the resulting modeled concentration change to the appropriate increment value, without regard to ambient background concentrations. (iv) If your projected emissions affect State areas with multiple class area designations, then you must reduce your projected emissions to meet the AAIs set out in the table in 40 CFR 52.21(c), according to the requirements for each class area. (v) If your proposed ERM are sufficient to reduce projected emissions, such that projected concentrations do not exceed any of the AAIs, you must then conduct the analysis described in § 550.307(b)(1)(vi). If your modeling results exceed the AAIs for any given air pollutant, then you must continue to apply additional ERM to sources to reduce that pollutant until additional modeling confirms that your projected concentrations do not exceed any AAI. Having done this, you must then conduct the analysis described in § 550.307(b)(1)(vi). (vi) You must conduct additional modeling, adding the appropriate background concentrations defined under § 550.302 and specified in § 550.304(e)(2) to your results, in order to determine the relevant design concentrations. You must compare the design concentrations for each criteria air pollutant with the NAAQS set out in 40 CFR part 50. If any of the NAAQS is exceeded for any air pollutant for any period of exposure, then you must propose additional ERM, and repeat the corresponding modeling, until you can demonstrate that your design concentrations do not exceed the NAAQS. (2) If your emissions affect any area designated as a non-attainment area, then you must evaluate BACT and other relevant ERM utilizing the process described for a short-term facility in § 550.306(a)(1) through (4) and consider all relevant ERM, including BACT. You must reduce the ambient impact of your emissions of all criteria air pollutants to a level that does not exceed the applicable SILs at 40 CFR 51.165(b)(2). You must conduct modeling using your revised projected emissions and compare the results with the SILs. If photochemical modeling is required under § 550.304, then you must also perform additional photochemical modeling and combine the results of that modeling with the results of the VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 subsequent dispersion models. If your results exceed any SIL for any criteria air pollutant for any averaging time, then you must apply additional ERM until additional modeling demonstrates that all projected emissions have been fully reduced so that no SIL is exceeded for any criteria air pollutant over any applicable averaging time. Having done this, you must then conduct the analysis described in § 550.307(b)(1)(vi). (c) Exceptions to the ERM requirement: (1) AAIs. For any averaging time other than an annual period, a facility’s projected emissions may cause an ambient impact that exceeds an applicable AAI one time during any rolling 12-month period for any given criteria air pollutant at any one location and still be considered to have fully reduced emissions. (2) NOX Waiver: If your projected emissions of NOX potentially affect a State coastal area, but you can demonstrate that those emissions would not cause an increase, or would cause a reduction, in the formation of O3 (i.e., reduce the O3 production efficiency), then no ERM are required for NOX, unless: (i) The potentially affected area is an attainment area for NOX and your analysis indicates that the AAIs for NOX would be exceeded in the absence of such ERM; or (ii) The potentially affected area is a non-attainment area for NOX. (3) VOC Waiver. A VOCs waiver could apply, as described in § 550.307(a)(3). (4) Safety exception. If the implementation of a plan under these regulations would compromise the safety of the operation of the facility, and such implementation of any air quality standards or benchmarks cannot be otherwise addressed, then BOEM may waive the requirement to apply ERM. (d) NAAQS requirement. No concentration of an air pollutant may exceed the concentration permitted under any primary or secondary NAAQS. (e) Emissions credits. You may propose to use emissions credits to achieve the equivalent reduction of emissions for any criteria air pollutant as an alternative to any other ERM, regardless of the attainment status of the State area affected by your potential emissions. § 550.308 Under what circumstances will BOEM require additional ERM on my proposed facility or facilities? (a) Regional Supervisor review. You may be required to apply additional ERM, on either a temporary or PO 00000 Frm 00096 Fmt 4701 Sfmt 4702 permanent basis, depending on the circumstances, even though you have demonstrated compliance with the sections above, if BOEM determines that your projected emissions or, where applicable, complex total emissions, may cause or contribute to a violation of a NAAQS. The Regional Supervisor may make this determination based on: (1) Information submitted by a State or local government, or a Federallyrecognized Indian tribe; (2) A cumulative impacts analysis conducted for an environmental impact statement (EIS) prepared to comply with the National Environmental Policy Act (NEPA); (3) A compliance review of your proposed plan under § 550.232(b) for an EP, or § 550.267(c) for a DPP or DOCD; or (4) The declaration by an adjacent State, or the USEPA, of an air quality emergency for a location that may be affected by air emissions generated by your operations. (b) Lessee’s or operator’s right to challenge. You will be given notice of the Regional Supervisor’s determination, as well as an opportunity to present additional information and analysis for review by the Regional Supervisor. If you present the Regional Supervisor with additional information and analysis, the Regional Supervisor will reassess whether your projected emissions, or complex total emissions, may cause or contribute to a violation of any NAAQS, and whether additional ERM will be required for your facility. The Regional Supervisor will then notify the State or local government, or Federally-recognized Indian tribe, and explain the reasons for this determination. § 550.309 ERM? What requirements apply to my (a) Sufficiency. Your proposed ERM must be sufficient to achieve actual emissions reductions corresponding to those reported in your plan for the duration of your plan’s operations under all reasonably foreseeable conditions. On a case-by-case basis, the Regional Supervisor will review your proposed ERM and make a determination whether such measures meet the applicable criteria. (b) Effectiveness. You must continually ensure the effectiveness of your ERM for the duration of your plan’s operations. If your measures become disabled or unavailable, you must immediately notify the Regional Supervisor and replace such ERM with others of equal or superior effectiveness within 30 days of discovering the disability or unavailability, unless the E:\FR\FM\05APP2.SGM 05APP2 asabaliauskas on DSK3SPTVN1PROD with PROPOSALS Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules Regional Supervisor approves an extension not to exceed 90 days. (c) Control efficiency. Your proposed ERM must reflect actual ECE. You must substantiate any ECE that you project and provide sufficient evidence to justify your ECE to the satisfaction of the Regional Supervisor. (1) Should your substantiating data indicate a range of ECE, you must utilize the more conservative estimates (i.e., those that would result in lower ECE) in your analysis and modeling. (2) ECE estimates of 100 percent are generally not acceptable, except in cases where there is clear and convincing and/or historical evidence to justify their use. (d) Emission reductions monitoring. If ERM are contained in your approved plan, the Regional Supervisor may require that you provide actual emissions data and/or any other information annually that the Regional Supervisor deems necessary to verify the effectiveness of your proposed ERM or their emission control efficiency. (1) If your plan is approved subject to the application of ERM, you must ensure that the emissions associated with each emissions source for which ERM is required complies with the emissions verification requirements of § 550.311. The Regional Supervisor may require that you install emissions measurement meters if the Regional Supervisor determines that such meters are necessary to ensure compliance with this requirement. (2) If you propose or are required to install emissions meters or any other monitoring equipment, you must collect and maintain monthly logs of the relevant meter or monitoring equipment readings. (e) Emissions credits. For emissions credits, the following requirements also apply: (1) You must acquire your emissions credits from emissions source(s), either offshore or onshore, that affect the air quality of the same AQCR. (2) For a CP, the emissions credits that you propose must provide a net air quality benefit for the same pollutant; for a precursor pollutant, any emissions credits that you propose must provide a net air quality benefit for that CP for which the pollutant is a precursor. (3) You must demonstrate to the Regional Supervisor that the emissions credit you propose binds you and any other parties who agree to lower their emissions. (4) You must also demonstrate that any emissions reductions will last for a period of time sufficient to ensure your plan’s continued compliance with the provisions of this subpart. The Regional VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 Supervisor may periodically require you to certify that the emissions reductions are still in place. (5) Any emissions credits must reduce emissions below rates otherwise required by law; (6) In addition to BOEM, you must notify the appropriate State air quality control jurisdiction of your proposal to acquire emissions offsets and, if necessary, its need to revise the State Implementation Plan to include the information regarding the emissions offsets you have acquired. You must provide evidence of such State notification to BOEM before you commence any operations that rely on the associated emissions credits. (7) Emissions credits are allowed in those circumstances where BOEM can readily verify the historical emissions from the facility to be used for the emissions credit, and the emissions reduction associated with the acquired emissions credit. (8) The approval of an emissions credit will be contingent upon receipt of proper documentation and will not be granted if such an emissions credit would require BOEM to engage in ongoing monitoring to verify continued compliance. (9) Nothing in these regulations is intended to restrict emissions credits from being obtained and shared by multiple lessees or operators. (f) Emission reduction measure(s) (ERM): Unless otherwise specified, you may employ any operational control, equipment replacement(s), BACT, or emissions credit, on either a temporary or permanent basis, to reduce the amount of emissions that would occur in the absence of such measures. Any proposed ERM will become a condition of your plan upon approval and could be required on either a permanent or temporary basis, depending on the circumstances and location of the proposed facilities. (1) In the event that you elect or are required to apply equipment replacement on a facility as the selected form of ERM, both the method of replacement and the equipment must comply with all other applicable federal regulations. (2) In the event that the equipment being replaced is part of an MSC subject to USCG regulation, such replacement must be implemented in such a manner as to comply with USCG regulations. § 550.310 How will revisions to the ambient air quality standards and benchmarks (AAQSB) affect my plan? (a) Review of plans. BOEM will evaluate the air pollutant emissions data submitted in your plan for compliance PO 00000 Frm 00097 Fmt 4701 Sfmt 4702 19813 with the AAQSB s in effect on the date your plan is deemed submitted. (b) Proposed plans. All activities described in initial, revised, modified, and supplemental plans must comply with the AAQSB in effect on the date the plan is deemed submitted, except: (1) If your plan was deemed submitted shortly after the effective date of a new or revised AAQSB, and you believe the immediate application of the new or revised AAQSB is impracticable or would otherwise impose an unreasonable hardship on your proposed operations, then you may request a deferral from the requirement to comply with the new or revised standard. The Regional Director will review your request and may with the concurrence of the Director grant a temporary deferral, not to exceed two years, from compliance with the new or revised AAQSB based upon a finding of impracticability or undue hardship. (2) Upon a finding that noncompliance with a new or revised AAQSB would not significantly affect the air quality of any State, the Director may grant a departure from compliance with the revised AAQSB. The Director may condition the departure upon any requirement(s) deemed necessary to avoid causing or contributing to a violation of the NAAQS. (c) Approved plans. (1) In order to ensure that your emissions remain compliant with any changes to the NAAQS, you are required to resubmit your plan for a periodic air quality review ten years after BOEM’s previous approval of your plan, as further defined in paragraph (c)(2) of this section. A plan resubmitted pursuant to this provision must be updated to comply with the requirements of § 550.205 as they exist at the time of the plan resubmission, including the most current data on emissions factors and MSC emissions, and must be reevaluated against the EETs and formulas as they exist at the time of the plan resubmission. When you resubmit a plan under this provision, that plan must include estimates for the annual projected emissions for the subsequent ten years, or for however long the plan’s facility or facilities would be expected to remain in operation, whichever is shorter. With respect to the emissions calculations for any given emissions source, the resubmitted plan must account for the most recent available data on the actual emissions of the relevant emission source. All of the applicable requirements of this subpart in effect on the date of resubmission apply on the same basis to a resubmitted plan as for an initial plan. E:\FR\FM\05APP2.SGM 05APP2 19814 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules (2) In order to ensure that your emissions remain compliant with OCSLA, starting in 2020, BOEM will conduct periodic reviews of plans approved prior to the effective date of the new exemption thresholds. To accomplish this, from that year forward, you must submit the air quality component of your previously approved plan according to the following schedule, regardless of whether you have a change in emissions. Year the plan was approved Prior to 1980 ............. 1980 through 1984 .... 1985 through 1989 .... 1990 through 1994 .... 1995 through 1999 .... 2000 through 2004 .... 2005 through 2009 .... 2010 through 2012 .... 2013 through 2014 .... 2015 through 2016 .... 2017 through 2018 .... 2019 through 2020 .... 2021 through 2022 .... 2023 and beyond ...... Year in which resubmission is required 2020. 2021. 2022. 2023. 2024. 2025. 2026. 2027. 2028. 2029. 2030. 2031. 2032. Ten years after year of approval. (i) The plan is due to BOEM on the same month as the month in which the plan was originally approved. (ii) For an initially approved plan, the lessee or operator is required to resubmit the plan in accordance with the table in paragraph (c)(2) of this section. (iii) If a revised, modified, resubmitted, or supplemental plan is submitted within ten years from the date of the initial plan submittal, the new resubmission date would be ten years from the date of approval of the revised, modified, resubmitted, or supplemental plan. (iv) If you fail to submit a revised plan as required under this section, then the previous approval of your plan is revoked. You may be subject to civil penalties or other appropriate sanctions for a regulatory violation, including the requirement to cease operations, as provided by 43 U.S.C. 1350. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS § 550.311 Under what circumstances will I be required to measure and report my actual emissions? (a) Compliance demonstration conditions. Under any of the following conditions, you must demonstrate that your actual emissions have at all times and continue to be in compliance with your previously approved plan: (1) Your plan is approved subject to the implementation of BACT or emissions credits; (2) Any emission source on your facility uses an engine that is not VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 certified by the USEPA consistent with the requirements of 40 CFR 1042 or 40 CFR 1043, for U.S.-flag vessels, or that is not certified to the MARPOL Annex VI Regulation 13 requirements as required by the Act to Prevent Pollution from Ships, for foreign-flag vessels operating in the U.S. (3) The Regional Supervisor determines that your projected emissions, or complex total emissions, for any criteria or precursor air pollutant, calculated on either an annual basis or on the basis of a 12month rolling sum, may significantly underestimate your actual emissions based either on historical data about your emissions sources or on ambient air monitoring. (4) BOEM determines that your facility causes or contributes to an exceedance of the NAAQS in any State. (b) Emissions reporting requirements.If you are required to make the demonstration described in this section: (1) Your measurement of actual emissions must include enough of your emissions sources to ensure that the actual emissions associated with facilities and MSCs operating under your approved plan are consistent with the projected emissions approved for your plan. You must consider every source that was included in your approved plan in addition to any source that would be classified as part of your projected emissions if your plan were resubmitted under the current regulations. (2) BOEM will consider various alternatives for reporting of relevant emissions sources. One option would be to monitor only the following key pieces of equipment: (i) For facilities, the required monitoring and reporting of engines would typically include: (A) Onboard facility engines; (B) Power generation engines; (C) Hydraulic power units (HPU) engines; (D) Deck cranes; (E) Cementing units; (F) Engines with a maximum power rating exceeding 200 hp (149 kW). (ii) For facilities, monitoring and reporting would typically exclude: (A) Propulsion engines; (B) Boilers and incinerators; (C) Emergency generators; (D) Lifeboat engines. (iii) For MSCs the sources, monitoring and reporting would likely include: (A) Propulsion engines; (B) Power generation engines; (C) Marine auxiliary engines; or, (D) Engines with a maximum power rating exceeding 200 hp (149 kW). PO 00000 Frm 00098 Fmt 4701 Sfmt 4702 (iv) MSCs monitoring and reporting would typically exclude boilers and incinerators, emergency generators, and any engines onboard science vessels, OSVs, or lifeboats. (3) Your demonstration must reflect your actual operations on the OCS and must be based exclusively on data derived from your actual equipment and not only on the basis of ECEs or fuel logs or activity data. (4) You must be able to demonstrate that the data submitted to BOEM under this section is consistent with any data provided to BOEM under the requirements of § 550.187. (5) You must provide the information required for this demonstration in a manner and on a schedule determined by the Regional Supervisor. (c) Notification requirements. If, on the basis of your demonstration of actual emissions, you determine at any time your actual emissions exceed your projected emissions for any pollutant you must notify BOEM and provide BOEM with the appropriate data regarding the exceedance. (d) Data submittal requirements. You must submit data and information in a format, and using the forms as specified by BOEM. You must submit information in an electronically-readable format, unless otherwise directed by the Regional Supervisor. If you transmit the information to BOEM electronically, you must use a delivery medium or transmission method authorized by BOEM. § 550.312 What post-approval recordkeeping and reporting is required? (a) Stack testing. If stack testing was used as a method to develop your emissions factors under § 550.205 or was used to develop any of the other information submitted pursuant to that section, then you must conduct the stack testing every three years and report the results, utilizing the General Provisions for Determining Standards of Performance for New Stationary Sources, Available at 40 CFR 60.8. (b) Fuel logs and activity data. In order to demonstrate compliance with your plan, you must retain information on monthly fuel consumption, for each emissions source, including attributed emissions sources, showing the quantity, type, and sulphur content of fuel used; collect facility and equipment usage information, including hours of operation at each percent of capacity for each emissions source. Venting, flaring, flashing and any other release of any air pollutant emissions that would not otherwise be accounted for by fuel consumption must be reported for any emissions source that generates criteria E:\FR\FM\05APP2.SGM 05APP2 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules air pollutants or precursor air pollutants in connection with OCS activities. (1) You must retain this information for a period of no less than ten years. You must submit this information to BOEM on a schedule set by the Regional Director. (2) If BOEM obtains the relevant data for your attributed emissions from an independent third party, then the Regional Supervisor may waive the requirement to submit fuel logs or collect facility and equipment usage information for MSCs. (3) Electronic Records. Recordkeeping and reporting must be consistent with the USEPA’s requirements for electronic reporting and recordkeeping requirements for new source performance standards. (c) Meteorological reporting. The Regional Supervisor may require, for a period of time and in a manner approved or prescribed, that you collect and report meteorological data from any of your facilities. The Regional Supervisor may allow you to substitute facility-specific data for meteorological data derived from any other mutually agreed upon location. (d) Other information. Notwithstanding any other provision within this subpart, the Regional Supervisor may require you to provide any other information within your possession, or otherwise reasonably obtainable, to support any finding or determination under this subpart. (e) Additional requirements imposed by other agencies. None of the provisions of this section would prevent the imposition of additional monitoring or reporting requirements on the part of BSEE or any other federal agency. asabaliauskas on DSK3SPTVN1PROD with PROPOSALS § 550.313 Under what circumstances will BOEM impose additional requirements on facilities operating under already approved plans? (a) BOEM may impose additional air quality requirements on facilities operating under already approved plans if an applicable AAQSB changes or if BOEM determines: (1) Your operations are causing or contributing to a violation of the NAAQS, either individually or in combination with any other offshore operations; (2) Your plan was approved with either a NOX waiver or a VOC wavier, and the air quality conditions in the affected State have changed to such an extent that your emissions of NOX or VOCs would contribute to an increase in the ambient O3 concentration such that the NAAQS for O3 may be exceeded (in an attainment area), or the NAAQS for O3 would continue to be exceeded (in an area that is non-attainment for O3). VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 (3) Your plan was approved with a NOX waiver, and the air quality conditions in the affected State have changed to such an extent that your emissions of NOX would contribute to an increase in the ambient concentration of NOX such that the NAAQS for NOX may be exceeded (in an attainment area), or the NAAQS for NOX would continue to be exceeded (in an area that is non-attainment for NOX). (4) Your operation is emitting unauthorized air pollutants; (5) Your operation is creating conditions posing an unreasonable risk to public health or welfare; or (6) Your operation is violating any applicable federal, State or tribal law related to air quality. (b) If a plan was approved for a shortterm facility that becomes a long-term facility, a new air quality plan must be submitted for the facility under the standards applicable to a long-term facility. If this reclassification resulted from adverse weather conditions, or other circumstances beyond your control, that prevented operations in your lease area, the Regional Director may grant a temporary exception for a period not to exceed the number of months that you were unable to operate. § 550.314 Under what circumstances will the Regional Supervisor review the projected emissions from my existing facility or facilities? (a) A State, or a Federally-recognized Indian tribe, may request the Regional Supervisor to supply it with the air pollution data regarding an existing facility’s projected emissions, when such data are needed either for the updating of the State’s emissions inventory or because a State believes an existing facility’s projected emissions may cause or contribute to a violation of the NAAQS. (b) The Regional Supervisor may require you to submit air pollutant emissions data to the State, or a Federally-recognized Indian tribe, submitting such a request. (c) The State, or a Federallyrecognized Indian tribe, submitting a request may submit information to BOEM that it believes indicates projected emissions from an existing facility may cause or contribute to a violation of the NAAQS. You will be given the opportunity to present information to the Regional Supervisor that demonstrates that your facility’s projected emissions do not cause such an effect. (d) The Regional Supervisor will evaluate the new information submitted and will determine, based on the emissions data, the available PO 00000 Frm 00099 Fmt 4701 Sfmt 4702 19815 meteorological data, and the distance of the facility from the SSB whether your actual emissions, including your attributed emissions, has the potential to cause or contribute to a violation of the NAAQS. (1) If the Regional Supervisor determines that your existing facility’s projected emissions are unlikely to cause or contribute to a violation of the NAAQS, the Regional Supervisor will notify the requesting State, or a Federally-recognized Indian tribe, and you and explain the reasons for this finding. (2) If the Regional Supervisor determines that your existing facility’s projected emissions have the potential to cause or contribute to a violation of the NAAQS, you must submit the additional information that the Regional Supervisor requests in order for BOEM to determine whether or not your existing facility causes or contributes to a violation of the NAAQS. You must submit this information within 120 days of the Regional Supervisor’s request, or within a longer period of time at the Regional Supervisor’s discretion. ■ 26. Add § 550.1012 to subpart J to read as follows: § 550.1012 What are the air quality requirements for pipeline rights-of-way holders? (a) When you apply for or acquire a ROW in any part of the OCS under the air quality regulatory jurisdiction of the Department, you must: (1) Include in your application the information required by § 550.205; and (2) Demonstrate that your activities will comply with the requirements of subpart C of this part. (b) For the purpose of this section: (1) Any requirement in either § 550.205 or subpart C of this part that refers to plans should be interpreted to apply equally to ROW applications except for the provision regarding the consolidation of multiple facilities (§ 550.303(d)) and for the periodic resubmission of plans (§ 550.310(c)); (2) Any requirement in either § 550.205 or subpart C of this part that refers to lessees or operators applies equally to ROW holders or grantees, except that no additional requirements apply to any proposed or existing pipeline ROW or lease term pipeline holders, that are already included within the scope of an existing or proposed exploration or development plan. (3) BOEM will notify BSEE of its determination that you have provided the information required by § 550.205 and met the requirements of subpart C of this part. If necessary, BOEM will E:\FR\FM\05APP2.SGM 05APP2 19816 Federal Register / Vol. 81, No. 65 / Tuesday, April 5, 2016 / Proposed Rules notify BSEE of additional conditions necessary to ensure that your activities will comply with subpart C of this part. [FR Doc. 2016–06310 Filed 4–4–16; 8:45 am] asabaliauskas on DSK3SPTVN1PROD with PROPOSALS BILLING CODE 4310–MR–P VerDate Sep<11>2014 22:26 Apr 04, 2016 Jkt 238001 PO 00000 Frm 00100 Fmt 4701 Sfmt 9990 E:\FR\FM\05APP2.SGM 05APP2

Agencies

[Federal Register Volume 81, Number 65 (Tuesday, April 5, 2016)]
[Proposed Rules]
[Pages 19717-19816]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2016-06310]

[[Page 19717]]

Vol. 81

Tuesday,

No. 65

April 5, 2016

Part II

Department of the Interior

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Bureau of Ocean Energy Management

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30 CFR Part 550

Air Quality Control, Reporting, and Compliance; Proposed Rules

Federal Register / Vol. 81 , No. 65 / Tuesday, April 5, 2016 /
Proposed Rules

[[Page 19718]]

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DEPARTMENT OF THE INTERIOR

Bureau of Ocean Energy Management

30 CFR Part 550

[Docket ID: BOEM-2013-0081]
RIN 1010-AD82

Air Quality Control, Reporting, and Compliance

AGENCY: Bureau of Ocean Energy Management (BOEM), Interior.

ACTION: Proposed rule.

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SUMMARY: This proposed rule would amend existing BOEM regulations
related to air quality measurement, evaluation, and control with
respect to oil, gas, and sulphur operations on the Outer Continental
Shelf (OCS) of the United States (U.S.), in the Central and Western
Gulf of Mexico (GOM) and the area offshore the North Slope Borough of
the State of Alaska, as part of the BOEM approval process for offshore
oil and gas exploration and development plans, right-of-use and
easement (RUE), pipeline rights-of-way (ROW), and lease term pipeline
applications. The proposed rule would: (1) Fulfill BOEM's statutory
responsibility under section 5(a)(8) of Outer Continental Shelf Lands
Act (OCSLA) by addressing all relevant criteria and major precursor air
pollutants and by cross-referencing BOEM standards and benchmarks for
those pollutants to those of the United States Environmental Protection
Agency (USEPA); (2) change the manner in which lessees would evaluate
and model vessel emissions attributed to OCS facilities; (3) change the
methods for measuring and evaluating air emissions including measuring
their impacts over State submerged lands; (4) provide a process by
which exemption thresholds are established and updated; (5) change the
circumstances when emission reduction measure(s) (ERM), including Best
Available Control Technology (BACT), are required, and establish new
criteria for the application of ERM; (6) formalize requirements for the
consolidation of emissions from multiple facilities; (7) consistent
with BOEM's existing regulatory authority, articulate a schedule and
requirements for ensuring that all plans, including those previously
approved, will remain compliant on an ongoing basis with these updated
regulations; and (8) include an air quality component in the submission
of RUE, ROW, and lease term pipeline applications.
Key policy changes include the following: (1) Aligning the list of
pollutants that are subject to an air quality review with the current
National Ambient Air Quality Standards (NAAQS) and cross-referencing
the ambient air quality standards and benchmarks (AAQSB) for those
pollutants to those of the USEPA; (2) formalizing the concept and
application of the term ``attributed emissions;'' (3) changing the
locations where air emissions will be measured and evaluated; and (4)
modifying the process by which exemption thresholds are established and
updated. This rulemaking would be the first major re-write of the OCS
air quality regulations in 35 years.

DATES: Submit comments on the substance of this rulemaking by June 6,
2016. Send your comments on the substance of the proposed rule to the
Department as directed in the ADDRESSES section below. Submit comments
on the information collection (IC) burden in this rulemaking to the
Office of Management and Budget (OMB) by May 5, 2016.

ADDRESSES: You may submit comments, identified by the number 1010-AD82,
by any of the following methods:
Federal rulemaking portal: https://www.regulations.gov.
Follow the instruction for submitting comments.
Mail: Department of the Interior, Bureau of Ocean Energy
Management, Office of Policy, Regulation, and Analysis, Attention:
Peter Meffert, 45600 Woodland Road, Sterling, Virginia 20166.
Hand delivery: Front Desk, Department of the Interior,
Bureau of Ocean Energy Management, Office of Policy, Regulation, and
Analysis, Attention: Peter Meffert, 45600 Woodland Road, Sterling,
Virginia 20166.
Please include your name, return address and phone number and/or
email address, so we can contact you if we have questions regarding
your submission.
Send comments on the IC of this rule to: Interior Desk Officer
1010-AD82, Office of Management and Budget; 202-395-5806 (fax); email
OIRA_Submission@eop.gov. Please also send a copy to BOEM at 45600
Woodland Road, Sterling, VA 20166.
Public Availability of Comments: BOEM does not consider anonymous
comments; please include your name and address as part of your
submittal. Before including your name, address, phone number, email
address, or other personal identifying information in your comment, you
should be aware 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 we will
be able to do so.

FOR FURTHER INFORMATION CONTACT: Peter Meffert, Bureau of Ocean Energy
Management, Office of Policy, Regulation, and Analysis, at
Peter.Meffert@boem.gov or mail to 45600 Woodland Road, Sterling,
Virginia 20166; or call (703) 787-1610.

SUPPLEMENTARY INFORMATION:

Table of Contents

I. General Information
A. What should I consider as I prepare my comments for BOEM?
1. Submitting Confidential Business Information (CBI)
2. Tips for Preparing Your Comments
B. Availability of Related Information
C. Abbreviations of Terms and Acronyms
II. Executive Summary
III. Background
A. Statutory Authority
B. Current Air Quality Framework--Air Quality Regulatory Program
C. Air Quality Regulatory Program Data Requirements
1. Projected Emissions
2. Maximum Potential Emissions
3. Processes, Equipment, Fuels, and Combustibles
4. Distance to Shore
5. Emission Reduction Measure(s) (ERM)
6. Non-Exempt Drilling Units
7. Documentation
D. Proposed Analytical Approach
1. Flowchart
2. Exemption Threshold Analysis
3. Modeling Analysis
4. Controls for Short-Term Facilities
5. Controls for Long-Term Facilities
6. Protection of Exceptional Natural Resources
7. Primary and Secondary National Ambient Air Quality Standards
(NAAQS) Evaluation
8. Intersection With the National Environmental Policy Act
(NEPA)
9. Additional Environmental Review
E. Conclusion
IV. Summary of Key Changes
A. Air Pollution Emissions Standards
B. Attributed Emissions
1. Emissions From Stationary Sources
2. Emissions From Mobile Support Craft
3. Determination of Attributed Emissions
4. Exclusion of Aircraft and Onshore Emissions Sources
C. Points of Measurement
1. Point-of-Origin Measurement
2. State Seaward Boundary (SSB)
3. Point-of-Impact Measurement
4. Ambient Air Quality Monitoring
D. Emission Exemption Threshold(s) (EETs)
E. Emission Reduction Measure(s) (ERM)
1. Emissions Credits and Offsets
2. Applicability of Best Available Control Technology (BACT)
Upon an Exceedance of the Significant Impact Levels (SILs)
3. ERM Evaluation Criteria

[[Page 19719]]

4. Nitrogen Oxides (NOX) Waiver and Volatile Organic
Compounds (VOC) Waiver
F. Consolidation of Emissions From Multiple Facilities
G. Ongoing Monitoring and Review of Projected Emissions
1. Recordkeeping and Measurement Criteria
H. Structure of the Proposed Rule
1. Potential Monitoring Alternative
2. Plan Resubmittals
I. Gulf-Wide Offshore Activities Data System (GOADS)
J. Prevention of Significant Deterioration
V. Section-by-Section Analysis of the Proposed Rule
A. 30 Code of Federal Regulations (CFR) Part 550, Subpart A
B. 30 CFR Part 550, Subpart B
C. 30 CFR Part 550, Subpart C
D. 30 CFR Part 550, Subpart J
VI. Interagency, Tribal, and Public Outreach
VII. Legal and Regulatory Analyses
A. Statutes
1. National Environmental Policy Act (NEPA) of 1969
2. Paperwork Reduction Act (PRA) of 1995
3. Regulatory Flexibility Act of 1980
4. Small Business Regulatory Enforcement Fairness Act of 1996
5. Unfunded Mandates Reform Act of 1995
B. Executive Orders (E.O.) and Presidential Memorandum
1. Governmental Actions and Interference With Constitutionally
Protected Property Rights (E.O. 12630) March 15, 1988
2. Regulatory Planning and Review (E.O. 12866) October 4, 1993
3. Civil Justice Reform (E.O. 12988) February 7, 1996
4. Protection of Children From Environmental Health and Safety
Risks (E.O. 13045) April 21, 1997
5. Federalism (E.O. 13132) August 10, 1999
6. Consultation and Coordination With Indian Tribal Governments
(E.O. 13175) November 6, 2000
7. Actions Concerning Regulations That Significantly Affect
Energy Supply, Distribution or Use (E.O. 13211) May 18, 2001
8. Enhancing Coordination of National Efforts in the Arctic
(E.O. 13689) January 21, 2015
9. Improving Regulation and Regulatory Review (E.O. 13563)
January 18, 2011
10. Presidential Memorandum of June 1, 1998 on Plain Language in
Government Writing

I. General Information

A. What should I consider as I prepare my comments for BOEM?

1. Submitting Confidential Business Information (CBI)
Do not submit CBI or proprietary information to BOEM through
www.regulations.gov or email. Clearly mark the part or all of the
information you claim to be CBI. For CBI information in a disk or CD
ROM you mail to BOEM, 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, submit a copy
of the comment that does not contain the information claimed as CBI for
inclusion in the public docket. Information so marked will not be
disclosed.
Any CD or data submitted to BOEM must be virus-free and usable, as
submitted. BOEM will not attempt to correct, fix or amend any CD or
other electronic media that is not readily accessible.
2. Tips for Preparing Your Comments
When submitting comments, remember to:
Identify the rulemaking by docket number and other
identifying information (subject heading, Federal Register (FR) date
and page number).
Organize Comments--When your comments respond to specific
provisions, organize your comments by referencing the relevant CFR part
or section number in the proposed rule.
Explain why you agree or disagree, and suggest
alternatives, and/or substitute language for your requested changes.
Describe any assumptions and provide any technical
information and/or data you used.
Provide specific examples to illustrate your concerns.
Explain your views as clearly as possible, avoiding the
use of profanity or personal threats.
Make sure to submit your comments by the comment period
deadline identified.

B. Availability of Related Information

A number of documents relevant to this air quality rulemaking,
including past and planned environmental studies and analysis, are
available on the BOEM Web site at www.BOEM.gov. In addition, the
economic and environmental analyses associated with this rulemaking are
available for inspection and copying in the BOEM docket for this
rulemaking, as identified above and are also available at www.BOEM.gov.

C. Abbreviations of Terms and Acronyms

The following are abbreviations of terms used in the preamble.

AAI Ambient Air Increment
AAQSB Ambient Air Quality Standards and Benchmarks
AEDT Aviation Environmental Design Tool (Federal Aviation
Administration)
AQCR Air Quality Control Region
AQRP Air Quality Regulatory Program
AQRV Air Quality Related Value
AQS Air Quality Subsystem (USEPA)
BACT Best Available Control Technology
BC Black Carbon (component of PM2.5)
BLM Bureau of Land Management
BOEM Bureau of Ocean Energy Management
BSEE Bureau of Safety and Environmental Enforcement
Btu IT British Thermal Unit International Tables
CAA Clean Air Act, as amended
CAMX Comprehensive Air Quality Model with Extensions
CBI Confidential Business Information
CEO Chief Environmental Officer (BOEM)
CFR Code of Federal Regulations
CH4 Methane
CMAQ Community Multi-scale Air Quality Model (USEPA)
CO Carbon Monoxide
CO2 Carbon Dioxide
CP Criteria Pollutant
CSU Column-Stabilized Units
DOCD Development Operations Coordination Document
DOI Department of the Interior
DPP Development and Production Plan
EC Elemental Carbon
ECE Emission Control Efficiency
EET Emission Exemption Threshold(s)
EEZ Exclusive Economic Zone
EIS Environmental Impact Statement
E.O. Executive Order
EP Exploration Plan
ERM Emission Reduction Measure(s)
FAA Federal Aviation Administration
FIRE Factor Information Retrieval System
FLM Federal Land Manager (Bureau of Land Management (BLM), United
States Fish and Wildlife Service (FWS), National Park Service (NPS),
and United States Department of Agriculture Forest Service (USFS))
FPS Floating Production System
FPSO Floating Production, Storage, and Offloading vessel
FR Federal Register
FWS Fish and Wildlife Service (DOI)
GAO Government Accountability Office
G&G Geological and Geophysical
GHG Greenhouse Gas
GOADS Gulf-wide Offshore Activities Data System
GOM Gulf of Mexico
H2S Hydrogen Sulfide
hp Horsepower
hpm Mechanical Horsepower
IC Information Collection
IRFA Initial Regulatory Flexibility Analysis
IRIA Initial Regulatory Impact Analysis
kW kilowatt
MACI Maximum Allowable Concentration Increase
MARPOL International Convention for the Prevention of Pollution from
Ships
MODU Mobile Offshore Drilling Unit
MSC Mobile Support Craft
NAAQS National Ambient Air Quality Standards
NEI National Emissions Inventory (USEPA)
NEPA National Environmental Policy Act of 1969
NESHAP National Emissions Standards for Hazardous Air Pollutants
NH3 Ammonia

[[Page 19720]]

NO2 Nitrogen Dioxide
NOX Nitrogen Oxides
N2O Nitrous Oxide
NPS National Park Service (DOI)
NSPS New Source Performance Standards
NSR New Source Review (USEPA)
NTC NOX Technical Code
NTL Notice to Lessees
O3 Ozone
OCS Outer Continental Shelf
OCSLA Outer Continental Shelf Lands Act of 1953, as amended
OIRA Office of Information and Regulatory Affairs (Office of
Management and Budget)
OMB Office of Management and Budget (Executive Office of the
President)
ONRR Office of Natural Resources Revenue (DOI)
OSV Offshore Supply Vessel
Pb Lead
PEMS Parametric Emissions Monitoring Systems
PM Particulate Matter
PM2.5 Fine Particulate Matter, 2.5 micrometers in
diameter or less
PM10 Particulate Matter, 10 micrometers in diameter or
less
PRA Paperwork Reduction Act of 1995
PSD Prevention of Significant Deterioration
PTE Potential to Emit
Pub. L. Public Law
RIA Regulatory Impact Analysis
ROV Remotely Operated Vehicle
ROW Right-of-Way
rpm Revolutions per minute
RUE Right of-Use and Easement
SBA Small Business Administration
SCC Source Classification Codes
SIL Significant Impact Level
SMOKE Sparse Matrix Operator Kernel Emissions
SO2 Sulphur Dioxide
SOB Statement of Basis
SOX Sulphur Oxides
SIP State Implementation Plan
SSB State seaward boundary
TAS Treatment as State
TIMS-Web Technical Information Management System Web-based
Application
TIP Tribal Implementation Plan
TLP Tension-Leg Platforms
tpy Tons per year
TSP Total Suspended Particulates
U.S. United States
USCG United States Coast Guard
U.S.C. United States Code
USEPA United States Environmental Protection Agency
USGS United States Geological Survey
VOC Volatile Organic Compound
[mu]g/m\3\ Micrograms per cubic meter

II. Executive Summary

The Outer Continental Shelf Lands Act (OCSLA) requires the
Department of the Interior (DOI) to promulgate regulations for
compliance with the National Ambient Air Quality Standards (NAAQS)
pursuant to the Clean Air Act (CAA) (42 U.S.C. 7401 et seq.), to the
extent that activities approved under OCSLA significantly affect the
air quality of any State (43 U.S.C. 1334(a)(8)). The U.S. Geological
Survey (USGS), a BOEM predecessor agency, prepared the first air
quality regulations under OCSLA, which were promulgated by the
Secretary of the Interior in 1980 (45 FR 15128, March 7, 1980). The
current version of these regulations is contained in 30 CFR part 550
(``Oil, Gas and Sulphur Operations in the Outer Continental Shelf'')
subparts A (``General''), B (``Plans and Information''), and C
(``Pollution Prevention and Control''). These regulations require: (1)
The submission of information on projected air emissions from offshore
oil and gas exploration or development activities with a proposed plan
for exploration (i.e., an exploration plan (EP)) or development (i.e.,
a Development and Production Plan (DPP) or a Development Operations
Coordination Document (DOCD); (2) the application of various emission
exemption thresholds to determine whether air quality impacts would be
presumed de minimis and, therefore, not require further BOEM review
under subpart C or whether the impacts would exceed the threshold and
require further review under subpart C; (3) the modeling of projected
emissions when a facility's projected emissions exceed the exemption
thresholds and would therefore potentially cause air quality impacts to
a State; \1\ and, (4) the control of an emissions source proposed for
any facility that would cause or contribute to an exceedance of the
AAQSB.
---------------------------------------------------------------------------

\1\ In the 1990 Clean Air Act Amendments, Congress added two
provisions authorizing Federally-recognized Indian tribes to be
treated like States under the CAA. Congress added section 301(d)
that authorizes the Administrator of the USEPA ``to treat Indian
tribes as States.'' In implementing this provision, the USEPA
published proposed rule entitled ``the Tribal Clean Air Act
Authority'' to implement this provision of the Act. In its proposed
rule (63 FR 7271, Feb. 12, 1998), the USEPA stated ``[The]
Regulations in this part identify those provisions of the Clean Air
Act for which Indian tribes are or may be treated in the same manner
as States. In general, these regulations authorize eligible tribes
to have the same rights and responsibilities as States under the
Clean Air Act and authorize EPA approval of tribal air quality
programs meeting the applicable minimum requirements under the
Act.'' Furthermore, in its ``EPA Statement of Policy on Consultation
and Coordination with Indian Tribes,'' dated May 4, 2011, on p. 3 in
the section entitled Guiding Principles, the USEPA states: ``EPA
recognizes and works directly with Federally-recognized tribes as
sovereign entities with primary authority and responsibility for
each tribe's land and membership, and not as political subdivisions
of states or other governmental units.'' Just as States establish
State Implementation Plans (SIPs) to comply with CAA/USEPA
requirements, the tribes can establish Tribal Implementation Plans
(TIPs) to regulate the air quality over tribal lands (which are then
outside the general jurisdiction of the State SIP). In addition, for
those tribes that have been granted ``treatment as State'' (TAS)
status (i.e., providing for Indian tribes to play essentially the
same role in Indian country that states do within State lands for
purposes of air quality management), BOEM will allow such a tribe to
appeal the approval of a plan, in a manner similar to that accorded
to States. For this reason, BOEM has proposed to expand the analysis
of impacts under its air quality rules to include potential impacts
to Federally-recognized Indian tribes having either TAS status or an
approved TIP.
---------------------------------------------------------------------------

BOEM is proposing to revise and replace its air quality regulations
with a new set of regulations that reflect a number of policy changes
with respect to the existing air quality regulatory program (AQRP (30
CFR 550 subpart C)). While the existing underlying framework would
remain the same in a number of key aspects, the proposed rule would
change in significant ways the manner in which BOEM regulates emissions
from certain sources on the OCS. The most significant changes in the
proposed rule relate to: (1) Fulfilling BOEM's statutory responsibility
under section 5(a)(8) of OCSLA by addressing all relevant criteria and
major precursor air pollutants and by cross-referencing the AAQSB for
those pollutants to those of the USEPA; (2) formalizing the concept and
application of the term ``attributed emissions;'' (3) changing the
methods for determining the locations from which air emissions will be
measured and evaluated; (4) modifying the process by which emission
exemption thresholds (EETs) are established and updated; (5) changing
the circumstances when ERM, including Best Available Control Technology
(BACT), are required, and establishing new criteria for the application
of ERM; (6) revising the boundary at which BOEM determines air quality
compliance to the State seaward boundary (SSB), rather than the
coastline; (7) formalizing requirements for the consolidation of
emissions from multiple facilities; (8) consistent with BOEM's existing
regulatory authority, articulating a schedule for ensuring that plans,
including previously approved plans, will be compliant with these
updated regulations; (9) adding an air quality component to the
submission of RUE, ROW, and lease term pipeline applications; (10) an
expanded use of offsets as an alternative in circumstances where BACT
was previously required; and (11) the addition of a new requirement for
all plans to be reviewed at least every 10 years, to ensure ongoing
compliance with the NAAQS, as amended from time to time.
BOEM is proposing to amend the current regulations to provide a
mechanism by which the regulations remain up-to-date in the future,
particularly when the USEPA changes an applicable AAQSB; to reflect the

[[Page 19721]]

recent statutory expansion of BOEM's air quality jurisdiction (42
U.S.C. 7627, as amended by Pub. L. 112-74); to improve the clarity of
existing regulatory provisions; to account for technological advances
in air quality measurement, evaluation, and reporting that have
occurred since the current regulations were promulgated; and to reflect
industry practices and procedures that have evolved since 1980.
BOEM is proposing to define a number of additional key terms, to
clarify the objectives and procedures associated with the AQRP, and to
reorganize a number of existing provisions in its regulations. The
proposed rule would consolidate all the existing data collection and
information requirements in a single section dedicated to air quality.
The pertinent provisions of BOEM's regulations related to air quality
would be either substantially updated or entirely replaced.
The proposed rule would make a number of changes to the existing
requirements associated with reporting, tracking, modeling, and
monitoring the air emissions from stationary facilities operating on
the OCS and emissions from associated non-stationary sources, including
vessels and vehicles, and aircraft traversing above the OCS or over
State submerged lands \2\ that operate in support of such facilities.
---------------------------------------------------------------------------

\2\ State submerged lands are the part of each State's territory
that extends from the shoreline up to the point of federal
jurisdiction (typically three miles from shore, but in some cases
extending up to nine miles from shore). In contrast, the offshore
lands under federal jurisdiction are referred to as the Outer
Continental Shelf (OCS).
---------------------------------------------------------------------------

Since BOEM's current air quality regulations were published in
1980, the USEPA has revised the NAAQS to include additional criteria
pollutants (i.e., to include Fine Particulate Matter, 2.5 micrometers
in diameter or less (PM2.5)), standards with a wider range
of averaging times and statistical forms.\3\ There are two types of
NAAQS: Primary NAAQS, which are intended to protect public health with
an adequate margin of safety; and secondary NAAQS, which are focused on
protecting public welfare.
---------------------------------------------------------------------------

\3\ In general, air quality standards are based on the
concentration of a given pollutant at a given location averaged over
a particular length of time, called the averaging time, evaluated in
combination with some statistical parameter, which is referred to as
the statistical form of the standard.
---------------------------------------------------------------------------

This proposed rule would enhance the process by which operators of
OCS facilities determine whether their proposed exploratory or
developmental activities could cause or contribute to a significant
adverse impact to the air quality of any State. It would define the
circumstances under which BOEM would require lessees and operators \4\
to control their air emissions in order to meet the USEPA's air
pollution control-related standards for criteria air pollutants (i.e.,
pollutants for which there are NAAQS) and major precursor air
pollutants. The proposed rule would incorporate by reference USEPA's
Significant Impact Levels (SILs), Ambient Air Increments (AAIs), and
the primary and secondary NAAQS. It would also make a number of changes
to ensure that certain provisions within BOEM's rules are automatically
updated whenever the USEPA updates its NAAQS, SILs and AAIs.
---------------------------------------------------------------------------

\4\ Although the rule refers to lessees or operators, the
provisions of the proposed rule would also apply to right-of-way
holders, right-of-use and easement holders, lease-term pipeline
applicants and any other party or parties that may be required to
submit a plan to BOEM for review and approval.
---------------------------------------------------------------------------

Because the USEPA's current NAAQS include standards for both annual
and short-term averaging times, the proposed rule would also provide
for the collection, evaluation, and consideration of data with respect
to the long-term and short-term exposure to air pollution originating
from the OCS. Under current BOEM regulations, most of the effects that
are evaluated relate to an annual exposure to a certain level of
pollution. Short-term averaging times measure something different,
namely the potential impact of a short-term exposure to the same
pollutant, where the level of pollution is much greater. In some cases,
the long-term exposure to low levels of pollution may be harmful; in
other cases, the short-term exposure to high levels of pollution may
also be harmful. Because the proposed rule would evaluate different
levels of exposure over different time periods, the proposed rule would
more accurately determine whether any OCS operations would have the
potential to cause an adverse effect to a State's air quality. The
proposed rule would require the modeling of emissions over any
averaging time that the USEPA has determined would be relevant whenever
the projected annual emissions of a given pollutant exceed the EETs.
This change would, therefore, enable BOEM to better ensure compliance
with all the NAAQS. This change is of particular relevance in the case
of nitrogen oxides (NOX) because that air pollutant is the
one for which the annual exemption threshold is most often exceeded.
In order to ensure ongoing compliance with the NAAQS referenced in
OCSLA, the proposed rule would also provide for the collection of
additional information on approved activities described in any initial,
revised, modified, resubmitted, or supplemental EP, DPP, or DOCD, or
application for a RUE, pipeline ROW, or lease term pipeline
(hereinafter referred to by the general term ``plan''), in order to
verify the information reported in the plan. As is the case with the
current BOEM regulations, the proposed rule would establish emissions
exemptions thresholds. The proposed rule would continue to require
facilities whose projected emissions of criteria and major precursor
pollutants would exceed the thresholds to model those emissions in
order to determine whether such emissions could potentially cause the
air quality of any State to exceed the NAAQS.
To ensure that OCS operations do not cause any such impact to the
air quality of a State, the proposed rule would require large emitters
of air pollutants, namely, those whose facilities exceed BOEM's EETs--
not only to project their emissions in their plan, but also to
demonstrate that their actual emissions do not exceed their projected
emissions (as contained in their original plan). To ensure ongoing
compliance, three major new procedures have been proposed. First, under
the proposed rule, if the USEPA revises any AAQSB that applies (NAAQS,
or any applicable SIL, or AAI), BOEM would examine the appropriateness
of its EETs, and, BOEM, at its discretion, would periodically revise
its EETs for the air pollutant(s) corresponding to USEPA's revision(s).
Second, certain large emitters would be required to develop a method
for measuring and reporting their emissions to demonstrate their actual
emissions do not exceed the original projections upon which approval
was granted. Third, starting in 2020,\5\ all lessees and operators with
previously approved plans would be required to update their plans with
then current emissions data, and BOEM would re-evaluate all of these
updated plans against the current EETs and for compliance with current
AAQSB, according to a schedule proposed in 550.310(c)(2). All lessees
and operators that submit plans would be required to include up-to-date
emissions data in their plans to ensure they comply with then current
AAQSB.
---------------------------------------------------------------------------

\5\ BOEM is proposing this date because BOEM expects that it
will have completed the studies to set new EETs by that time.
---------------------------------------------------------------------------

Although BOEM does not issue air quality permits and instead
reviews air emissions in the context of its AQRP, BOEM recognizes that
a one-time review of a particular facility's compliance with AAQSB may
not be adequate to ensure that the facility does not cause or

[[Page 19722]]

contribute to a violation of the NAAQS within a State. USEPA
periodically updates the NAAQS and adds new averaging times and
statistical forms for the various indicator pollutants. Measurement and
evaluation techniques and methods are expected to improve over time.
Equipment ages and becomes less efficient as it does so. The types and
characteristics of support vessels, vehicles and aircraft may change.
For these and various other reasons, BOEM has proposed that evaluating
a plan's effectiveness more than once may aid BOEM in ensuring
``compliance with the national ambient air quality standards pursuant
to the Clean Air Act (42 U.S.C. 7401 et seq.), to the extent that
activities authorized under [OCSLA] significantly affect the air
quality of any State'' (43 U.S.C. 1334(a)(8)). Consistent with the
requirement in every offshore lease that lessees and operators are
required to comply with changes to the regulations, as they are
refined, BOEM is proposing plans be reevaluated periodically for air
quality purposes.\6\
---------------------------------------------------------------------------

\6\ See Sec. 550.310(c)(2), below, of the proposed rule text.
---------------------------------------------------------------------------

Finally, this rule proposes to codify the existing mechanism BOEM
uses in the GOM OCS Region to report ongoing emissions information
(i.e., the Gulf-wide Offshore Activities Data System or GOADS, as
described in Notice to Lessees and Operators ([NTL], BOEM NTL No. 2014-
G01) and apply it to all OCS regions under BOEM air quality
jurisdiction. This information is important to ensure that OCS
activities authorized by BOEM do not cause any State to exceed the
NAAQS. BOEM also uses this information in its National Environmental
Policy Act (NEPA) documents at several stages of the OCS leasing and
plan review and approval process. In addition, BOEM shares this data
with the USEPA to enhance its national emissions inventory (NEI), and
with States and local air quality management agencies for the
development of State Implementation Plans (SIPs). In-addition, BOEM
collects emissions information related to Greenhouse Gases (GHGs) on a
regular basis as part of the GOADS program and provides this
information to lessees and operators to facilitate their reporting to
the USEPA.

III. Background

A. Statutory Authority

OCSLA grants DOI authority to issue leases for the development of
the nation's energy and mineral resources on the OCS. The U.S. OCS
extends from three to nine nautical miles (nm) offshore (this varies by
State) to the extent of U.S. claimed jurisdiction and control, which is
200 nm or more from the coastal States' baseline.\7\ BOEM makes OCS
resources available for expeditious and orderly development through
leasing, subject to environmental safeguards, in a manner that is
consistent with the maintenance of competition and other national needs
(43 U.S.C. 1332(3)). In 1978, OCSLA was amended to include a
requirement for DOI to promulgate regulations for ``compliance with the
national ambient air quality standards pursuant to the CAA (42 U.S.C.
7401 et seq.), to the extent that activities authorized under [OCSLA]
significantly affect the air quality of any State'' (43 U.S.C.
1334(a)(8)). In 1980, the USGS, a BOEM predecessor agency responsible
for overseeing OCS energy and mineral activity, promulgated air quality
regulations for activities authorized on the entire OCS, which are now
BOEM's air quality regulations.
---------------------------------------------------------------------------

\7\ The official U.S. coastal baseline is recognized as the low-
water line along the coast in accordance with the articles of the
United Nations Convention on the Law of the Sea, art. 76, Dec.10,
1982, 1833 U.N.T.S. 3, 428. The territorial sea extends seaward 12
nautical miles (nm) from the baseline. The Exclusive Economic Zone
(EEZ) extends from the outer boundary of territorial sea seaward to
200 nm. The continental shelf begins at 12 nm, includes the EEZ and
may extend further. The U.S. OCS extends from the SSB to the extent
of the continental shelf. See 43 U.S.C. 1331(a); see also 43 U.S.C.
1301.
---------------------------------------------------------------------------

In 1990, Congress amended section 328 of the CAA and transferred
authority to regulate air emissions on the OCS, other than in the
Central and Western GOM, from DOI to the USEPA. In 2011, Congress again
amended section 328 to transfer the authority for regulating air
emissions from the USEPA back to DOI for those parts of the OCS
adjacent to the North Slope Borough of the State of Alaska. As of the
publication of this proposed rule, DOI's jurisdiction for ensuring
compliance with the NAAQS pursuant to the CAA includes OCS areas
adjacent to Texas, Louisiana, Mississippi, Alabama, and the North Slope
Borough of the State of Alaska.

B. Current Air Quality Framework--Air Quality Regulatory Program

Congress has geographically divided air quality regulatory
authority for authorized OCS activities between the USEPA and BOEM,
based upon where those activities occur on the OCS. While the overall
objectives of BOEM's and the USEPA's air quality regulations are
similar, there are differences in each agency's statutory authority and
differences in the way each agency implements its statutory charge. The
USEPA implements its charge through permitting (CAA Sections 165 and
173). The CAA directs the USEPA to establish requirements to control
air pollution from sources on the OCS to attain and maintain federal
and State ambient air quality standards and to comply with the
provisions of part C of subchapter I of the CAA (CAA Section 328(a)).
USEPA regulations for permitting OCS sources ``ensure that there is a
rational relationship to the attainment and maintenance of federal and
State ambient air quality standards and the requirements of part C of
title I, and that the rule is not used for the purpose of preventing
exploration and development of the OCS'' (40 CFR 55.1). The USEPA's OCS
air quality regulations incorporate requirements derived from other
areas of the CAA and USEPA regulations and for sources within 25 miles
of the State boundary require compliance with local rules as if the
source were located onshore, the result of which is that operators must
demonstrate compliance with several different types of requirements.
BOEM's jurisdiction under 43 U.S.C. 1334(a)(8) requires BOEM to
promulgate regulations ``for compliance with the national ambient air
quality standards pursuant to the [CAA] . . . to the extent that
activities under OCSLA significantly affect the air quality of any
State.'' Thus, regulations implementing this section regulate offshore
emissions specifically to protect State air quality rather than
protecting air quality above the OCS generally. Upon submission by a
lessee or operator of a plan, BOEM will determine whether the plan is
consistent with the OCSLA and BOEM's regulations. If BOEM determines
that a plan is inconsistent with OCSLA or BOEM's regulations, BOEM will
require modifications of the plan as necessary to achieve consistency.
BOEM may approve, require modification of, or disapprove an EP. BOEM
can disapprove an EP only if there are no possible modifications that
would avoid ``serious harm or damage to life (including fish and other
aquatic life), to property, to any mineral (in areas leased or not
leased), to the national security or defense, or to the marine,
coastal, or human environment,'' as described in 43 U.S.C.
1334(a)(2)(A)(i). With respect to a DPP or a DOCD, BOEM must approve,
disapprove, or require modification of the plan after conducting a
compliance review, which includes compliance with the regulations
implementing section 1334(a)(8). In addition, the timing of BOEM's
decisions is also circumscribed

[[Page 19723]]

by the provisions of OCSLA. Under OCSLA, BOEM is required to approve a
plan within 30 days for an EP or within 60 days for a DPP or DOCD, if
BOEM finds that the plan is consistent with OCSLA and its implementing
regulations, including those ensuring air quality compliance under
section 5(a)(8) of OCSLA. (See 43 U.S.C. 1340(c) and 1351(h)).
BOEM's predecessor, USGS, developed the current air quality
regulatory framework in 1980 to address potential onshore air quality
impacts of OCS operations on adjacent States. These regulations require
lessees or operators to submit information on projected air emissions
in their proposed EPs, DPPs and DOCDs. BOEM considers air emissions
information submitted by lessees and operators as one component of its
review of the overall exploration or development plan. The regulatory
process by which BOEM evaluates the submitted emissions information is
referred to in this document as BOEM's AQRP. The 1980 regulations first
established a process for determining whether the potential air quality
impacts from any given plan are low enough that they should be exempt
from further air quality regulatory analysis. Plans that do not exceed
these EETs are generally exempt from further analysis. For plans that
exceed these exemption thresholds, BOEM regulations require lessees and
operators to conduct modeling intended to help BOEM determine whether
emissions from any facility could cause an exceedance of the AAIs or
NAAQS onshore, and if so, what mitigation (i.e., emissions reduction)
measures, if any, BOEM should impose on those proposed exploration and
development activities to reduce the potential impacts to affected
States.
BOEM conducts its AQRP analysis whenever a lessee or operator
proposes new exploration, development, or production operations on the
OCS or submits a revised or supplemental plan, which would modify
operations in a manner that could cause an increase in the release of
regulated pollutants above the amounts described in a previously
approved plan. The AQRP focuses on the impact of emissions from a
specific exploration or development and production project and its
potential onshore impacts on air quality. The AQRP does not directly
regulate OCS air quality, since 43 U.S.C. 1334(a)(8) requires BOEM to
focus its plan review on the potential impacts to the air quality of
the States. The AQRP consists of a quantitative review of specific air
quality data that informs a decision to approve, require modification
of, or disapprove a specific plan. Any modifications BOEM requires as a
result of the AQRP review become an enforceable provision of the
approved plan. As BOEM fulfills its statutory obligation, its AQRP also
achieves other objectives: (1) To protect public health from adverse
air quality effects; (2) to protect public welfare by preventing a
deterioration in the air quality of the environment (e.g., to protect
crops, forests, and wildlife); (3) to prevent the formation of new
designated non-attainment areas; and, (4) to preserve and prevent
degradation of the air quality in national parks and other areas of
special natural, recreational, scenic, or historic value. In practical
terms, this is accomplished by assessing whether OCS operations and
activities will advance these objectives. The AQRP is one factor that
BOEM considers in making a determination on the overall plan.
The AQRP analysis is intended to account for emissions of
pollutants considered harmful to public health and the environment from
facility and associated support craft. The plan must include
descriptions of all relevant emissions sources--offshore, stationary
and nonstationary, and certain onshore ones--regardless of whether they
are intended to be used on a short-term or long-term basis, and
regardless of attainment status. As part of the AQRP analysis, BOEM
currently evaluates the emissions of most pollutants that the USEPA has
designated as NAAQS ``criteria pollutants'' (CPs) in the USEPA's air
quality regulatory scheme. The USEPA currently defines the following
six pollutants as CPs: Carbon monoxide (CO); nitrogen dioxide
(NO2); sulphur dioxide (SO2); ozone
(O3); particulate matter (PM); and lead (Pb). BOEM evaluates
air emissions using the NAAQS as a standard because OCSLA provides that
BOEM must ensure compliance with the NAAQS (43 U.S.C. 1334(a)(8)). At
the time the current regulations were promulgated, BOEM's predecessor,
USGS, determined that Pb was generally not released in sufficient
quantities from offshore oil and gas operations to warrant a separate
analysis, and so BOEM does not currently review Pb data as part of the
AQRP. Also, as of 1980, the USGS had determined that there was no way
to review O3 formation directly, but it instead decided to
regulate O3 formation indirectly, through the tracking of
O3 precursor pollutants, volatile organic compounds (VOCs)
and NOX.
In addition to regulating CPs, BOEM currently regulates most of the
major precursor pollutants that lead to the formation of the CPs. Some
CPs are also precursors for other CPs. For example, USEPA has
identified SO2 as a precursor to the formation of
PM2.5, which is PM that is 2.5 micrometers in diameter or
less, and both are CPs. BOEM's current regulations address two
precursor pollutants of ozone, NOX and VOCs. Ammonia
(NH3) is not currently covered by BOEM's regulations but is
proposed to be regulated in this proposed rule, because it may be
regulated under the Clean Air Act as a precursor pollutant to the
formation of PM2.5.
The USEPA has found that GHG \8\ emissions endanger the public
health and welfare (74 Federal Register (FR) 66496, Dec. 15, 2009).
BOEM recognizes that the continued and prospective emissions of GHGs
from offshore oil and gas operations will contribute to global GHG
concentrations.\9\ The goal of this rule, however, is to implement
Section 5(a)(8) of OCSLA, which requires BOEM to regulate air quality
so as not to allow exceedances of the NAAQS in any State. While GHGs
are not regulated under the NAAQS and are currently being addressed by
the USEPA through other sections of the CAA, climate change itself
impacts air quality, particularly ground-level ozone, and has
consequential health impacts associated with poor air quality.\10\
However, because GHGs are not regulated under the NAAQS, Section
5(a)(8) of OCSLA specifically is not the appropriate statutory vehicle
to address the harm that GHGs cause and BOEM is not proposing to
address the issue of GHG emissions in this proposed rule.
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\8\ GHGs are defined by the USEPA as the aggregate group of the
following six greenhouse gases: Carbon dioxide (CO2),
methane (CH4), nitrous oxide (N2O),
hydrofluorocarbons (HFCs), perfluorocarbons (PFCs), and sulfur
hexafluoride (SF6). See, e.g., 40 CFR 52.21(b)(49)(i).
\9\ More recently, in the preamble to its proposed new source
performance standards for the oil and gas industry, the USEPA
provided an update regarding the climate change impacts that result
from GHG emissions (80 FR 56593, 56602, Sept. 18, 2015). Many of the
numerous impacts identified by the USEPA, such as increased severity
of storms, increased water pollution (including ocean
acidification), rising sea levels, loss of sea ice, and habitat
loss, relate to coastal areas and the natural resources of the OCS.
Both the 2009 endangerment finding and the recent proposed new
source performance standards underscore that these impacts will
exacerbate ongoing environmental pressures in Alaska, and will
particularly impact Alaska native communities.
\10\ See 74 FR 66496 (No. 239, December 15, 2009),
``Endangerment and Cause or Contribute Findings for Greenhouse Gases
Under Section 202(a) of the Clean Air Act,'' or the United States
Global Change Research Program (USGCRP) National Climate Assessment,
available at https://nca2014.globalchange.gov/report or the
Intergovernmental Panel on Climate Change (IPCC) reports available
at https://www.ipcc.ch/.
---------------------------------------------------------------------------

The Bureau, however, is still interested in addressing GHGs

[[Page 19724]]

consistent with its legal authorities. Lessees and operators currently
submit to the NEI the results of BOEM's calculation of GHG information
as part of GOADS, and GHG emissions are considered as part of the NEPA
review of lease sales and post-lease approvals. In the coming months,
BOEM will engage stakeholders regarding potential avenues to address
GHG emissions, as appropriate, either through a separate rulemaking or
some other action.
Separate but related to the GHG issue is the matter of black carbon
(BC) dispersion and deposition in Alaska and other parts of the Arctic,
which is an environmental concern. BC is a component of
PM2.5, and as such would be a component of a CP that will be
regulated under the proposed rule.\11\ The ambient concentrations of
PM2.5, including BC, would be considered in any analysis of
the pre-existing background pollution levels before any plan could be
approved for development on the OCS. Recent scientific studies \12\
have indicated that BC can be a source of negative health effects.\13\
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\11\ Black carbon is not classified as a unique CP and the USEPA
does not directly regulate its emissions other than as a component
of PM2.5.
\12\ For example, ``Black Carbon Exposures, Blood Pressure, and
Interactions with Single Nucleotide Polymorphisms in MicroRNA
Processing Genes,'' in Environmental Health Perspectives, 118:943-
948 (2010), and ``Long-Term Exposure to Black Carbon and Carotid
Intima-Media Thickness: The Normative Aging Study'' in Environmental
Health Perspectives, 121:1061-1067 (2013). Web addresses for these
studies described are at: https://www.jstor.org/stable/27822949?seq=1#page_scan_tab_contents and https://dash.harvard.edu/handle/1/11877015.
\13\ Based on an assessment of the scientific evidence for
health effects associated with exposures to ambient PM, in the most
recent review of the NAAQS for PM, the USEPA concluded that ``many
constituents of PM can be linked with differing health effects and
the evidence is not yet sufficient to allow differentiation of those
constituents or sources that are more closely related to specific
health outcomes'' (PM Integrated Science Assessment (ISA), section
2.4.4).
---------------------------------------------------------------------------

BOEM is actively investigating this issue and our evaluation of the
potential impacts of BC and a determination of appropriate controls is
continuing to evolve. BOEM and the USEPA are coordinating their efforts
on this matter.
In addition to the health effects associated with the
PM2.5 emissions that include BC, there are also potentially
significant implications to climate change and global warming from BC.
These relate primarily to three factors: (1) BC particles directly
absorb sunlight and reduce the planetary albedo \14\ when suspended in
the atmosphere; (2) BC absorbs incoming solar radiation, disturbs the
temperature structure of the atmosphere, and influences cloud cover;
and (3) when deposited on high albedo surfaces like ice and snow, BC
particles reduce the total surface albedo \15\ available to reflect
solar energy back into space. Small initial snow albedo reduction may
have a large radiative forcing effect \16\ because of a positive
feedback: Reduced snow albedo increases surface temperatures and the
increased surface temperature decreases the snow cover and further
decreases surface albedo.\17\
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\14\ Albedo is the fraction of solar energy (shortwave
radiation) reflected from the Earth back into space. It is a measure
of the reflectivity of the earth's surface. Ice, especially with
snow on top of it, has a high albedo: Most sunlight hitting the
surface bounces back towards space.
\15\ Total surface albedo is the diffuse reflectivity or
reflecting power of a surface. It is the ratio of reflected
radiation from the surface to incident radiation upon it. In this
case, the reduction in total surface albedo would represent the
reduction in albedo that is caused by the relevant OCS operations in
the vicinity of the project or development that is generating BC
emissions.
\16\ Radiative forcing or climate forcing is defined as the
difference of insolation (sunlight) absorbed by the Earth and energy
radiated back to space.
\17\ Mollie Bloudoff-Indelicato (January 17, 2013). ``A Smut
Above: Unhealthy Soot in the Air Could Also Promote Global Warming:
Atmospheric black carbon is not only bad for the lungs, but can also
act as greenhouse particles under certain circumstances.''
Scientific American. January 22, 2013.
IPCC, Changes in Atmospheric Constituents and in Radiative
Forcing, in Climate Change 2007: The Physical Science Basis.
Contribution Of Working Group I To The Fourth Assessment Report Of
The Intergovernmental Panel On Climate Change 129, 132 (2007),
available at https://www.ipcc.ch/ipccreports/ar4-wg1.htm. (Magnitudes
and uncertainties added together, as per standard uncertainty
rules).
V. Ramathan and G. Carmichael, Global and regional climate
changes due to black carbon, 1 NATURE GEOSCIENCE 221-22 (23 March
2008) (``The BC forcing of 0.9 W m-2 (with a range of 0.4 to 1.2 W
m-2) . . . is as much as 55% of the CO2 forcing and is
larger than the forcing due to the other GHGs such as
CH4, CFCs, N2O or tropospheric ozone.'').
---------------------------------------------------------------------------

While BOEM does not currently have sufficient data to support a
specific limit on BC, the exemption thresholds research study currently
underway for the Gulf of Mexico (which is described in detail in
section III.D.1, under the heading of ``Exemption Threshold Analysis'')
will analyze BC as part of the overall review. The study will apply the
Community Multi-scale and Air Quality (CMAQ) Model and the
Comprehensive Air Quality Model with Extensions (CAMX)
photochemical grid models, as part of the analysis. PM emissions
specified in the emissions inventory will be allocated to individual PM
species \18\ as part of the Sparse Matrix Operator Kernel Emissions
(SMOKE) emissions processing and modeling system \19\ using PM
speciation factors obtained from USEPA's SPECIATE database \20\ for
each source category (as defined by the Source Classification Code
(SCC)). This evaluation will result in PM mass being broken into the
mass associated with elemental carbon (EC), organic carbon, and other
elements, as well as particle bound VOCs, such as polycyclic aromatic
hydrocarbons. BC is essentially equivalent to the EC portion of PM.
CMAQ \21\ and CAMX \22\ model projections of EC will be
calculated and modeled for further analysis. This will be done both for
the domain defined for the study (see section III.D.1), and for
specific sources. Two other models commonly used by the industry and
BOEM to evaluate air quality, AERMOD \23\ and CALPUFF,\24\ are being
considered for use and will apply a similar technique to apportion
PM2.5 mass for a BC analysis.
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\18\ There are many forms of PM. The U.S. National Research
Council has emphasized the importance of examining the risk of PM
species (``Research Priorities for Airborne Particulate Matter: IV:
Continuing Research Progress.'' Washington, DC, National Research
Council, 2004). Determining the differential toxicity of
PM2.5 species and identifying species with greatest
toxicity is of great importance to emission-control strategies and
regulations. These investigations have reported numerous components
that may be responsible for particle toxicity, such as elemental and
organic carbon, sulfate, nitrate, and metals including zinc, nickel,
iron, potassium, and chromium.
\19\ See the following site for additional information on the
SMOKE modeling system: https://cmascenter.org/smoke/.
\20\ SPECIATE is the USEPA's repository of volatile organic gas
and PM speciation profiles of air pollution sources. For additional
information, see: https://www.epa.gov/ttnchie1/software/speciate/.
\21\ Further information on CMAQ is available at: https://www.fhwa.dot.gov/environment/air_quality/cmaq/.
\22\ Further information on CAMX is available at: https://www.camx.com/.
\23\ AERMOD is described in detail in the publication, ``AERMOD:
DESCRIPTION OF MODEL FORMULATION,'' U.S. Environmental Protection
Agency, EPA-454/R-03-004, September 2004, available at: https://www.epa.gov/scram001/7thconf/aermod/aermod_mfd.pdf.
\24\ CALPUFF is an advanced non-steady-state meteorological and
air quality modeling system adopted by the USEPA in its Guideline on
Air Quality Models as the preferred model for assessing long range
transport of pollutants and their impacts on federal Class I areas
and on a case-by-case basis for certain near-field applications
involving complex meteorological conditions. Further information on
this model is available at: https://www.src.com/.
---------------------------------------------------------------------------

BOEM requests comments and data on the extent of BC emissions from
OCS-related operations and potential means of reducing such emissions
and their negative effects. BOEM also requests comment on other
factors, information, or data that BOEM should consider in its analysis
of BC, either in connection with or in addition to its air quality
regulatory analysis.

[[Page 19725]]

C. Current Air Quality Regulatory Program Data Requirements

As explained above, BOEM's AQRP review, conducted under existing
regulations at 30 CFR part 550 subparts B and C, is triggered when a
lessee or operator submits or resubmits an exploration or development
plan. With respect to air quality, BOEM currently requires the
submitter to provide the following information:
1. Projected Emissions
Under existing BOEM regulations, the lessee or operator must
provide tables showing the projected air emissions of all regulated
criteria and major precursor pollutants, except PM2.5, Pb,
and O3,\25\ generated by the submitted plans. In addition,
for each source for each pollutant, lessees must identify: The
projected hourly emissions rate in peak pounds per hour; the total
projected annual emissions in tons per year (tpy); the frequency and
duration of projected emissions; and all projected emissions over the
duration of the plan (i.e., for as many years as the operations will
continue).
---------------------------------------------------------------------------

\25\ Existing BOEM air pollution prevention and control
regulations (30 CFR part 550 subpart C) apply air quality standards
and screening methods current as of 1980. At that time
PM2.5 was not regulated and all PM was considered as
total suspended particulates (TSP). Neither Pb nor O3
were included in the USEPA's screening methods under 40 CFR 52.21(c)
or 40 CFR 165(b)(2).
---------------------------------------------------------------------------

2. Maximum Potential Emissions
The lessee or operator must base all of its projected air emissions
identified in (1) above on the maximum rated capacity of the equipment
on the plan's drilling unit or facility.
3. Processes, Equipment, Fuels, and Combustibles
The lessee or operator must provide a description of processes,
processing equipment, combustion equipment, fuels, and storage units,
including the characteristics and the frequency, duration, and maximum
burn rate of any well test fluids to be burned.
4. Distance to Shore
The lessee or operator must provide the distance between any given
facility and the closest shoreline of an adjacent State.
5. Emission Reduction Measures (ERM)
Each lessee or operator must describe any proposed air emission
reduction measures (ERM), including a description of the relevant
source(s), the emission reduction control technologies or procedures,
the quantity of reductions to be achieved, and any monitoring system
proposed to measure emissions.
6. Reductions in Emissions From Non-Exempt Drilling Units
The lessee or operator must provide a description of how the lessee
or operator intends to address the emissions generated, if emissions
from the plan are greater than the lessee's or operator's respective
emission-exemption amounts and if modeling indicates that some form of
emissions reductions will be necessary.
7. Documentation
The lessee or operator must document the basis for all of its
calculations, including engine size, rating, and applicable operational
information. In the GOM region, BOEM and industry have historically
used worksheets contained in forms BOEM-0138 (Gulf of Mexico Air
Emissions Calculations for EPs) and BOEM-0139 (Gulf of Mexico Air
Emissions Calculations for DOCDs) for air quality information.

D. Proposed Analytical Approach

1. Flowchart
The following flow chart illustrates the analytical approach that a
lessee or operator would use to evaluate its projected emissions under
this proposed rule. The flow chart is intended for informational
purposes only. In any circumstances where the flow chart may be
interpreted to conflict with the regulatory text, the regulatory text
is controlling.
[See attached flowchart]
BILLING CODE 4310-MR-C

[[Page 19726]]

[GRAPHIC] [TIFF OMITTED] TP05AP16.000

[[Page 19727]]

[GRAPHIC] [TIFF OMITTED] TP05AP16.001

[[Page 19728]]

[GRAPHIC] [TIFF OMITTED] TP05AP16.002

[[Page 19729]]

[GRAPHIC] [TIFF OMITTED] TP05AP16.003

While many significant changes would be made to BOEM's AQRP under
the proposed rule, the analytical framework remains fundamentally the
same. Under both the current regulations and the proposed rule, the

[[Page 19730]]

lessee or operator must perform the following fundamental steps: (1)
Identify and describe the characteristics of all the relevant emissions
sources; (2) calculate the emissions associated with these sources; (3)
determine which emissions should properly be allocated to the lessee's
or operator's plan; (4) compare the emissions totals, on a per-
pollutant basis, to a series of exemption formulas; (5) apply ERMs to
sources of VOC emissions that exceed the VOC exemption threshold; (6)
conduct modeling of the potential impacts for any criteria pollutant
that exceeds an exemption threshold and compare against various AAQSB;
and (7) propose emission reduction measure(s) as necessary to ensure
compliance with those standards and benchmarks. The ``Summary of Key
Changes'' section of this preamble outlines the major changes included
in this proposed rule. While the basic steps of the AQRP process would
remain similar, the proposed rule would alter how the data are
gathered, the standards and benchmarks against which the data are
evaluated, and the process by which the air quality information is
reviewed.
BOEM's current air quality evaluation methodology is based in large
part on the USEPA's New Source Review (NSR) pre-construction permitting
program.\26\ Under one part of that program, USEPA uses pollutant-
specific emission rates (called Significant Emissions Rates) to
determine whether a permit applicant is required to conduct an ambient
air quality analysis for each pollutant.\27\ If so, USEPA then uses
concentration levels known as SILs to help determine whether an
individual source will cause or contribute to an exceedance of the
NAAQS and the level of analysis necessary to make that determination.
---------------------------------------------------------------------------

\26\ The NSR pre-construction permitting program is mainly
composed of two parts: The Prevention of Significant Deterioration
(PSD) program in attainment areas and the New Source Review Program
for non-attainment areas. The PSD program applies to any ``major
emitting facility,'' including any OCS source, that commences
construction or undertakes a major ``modification'' in an attainment
area (CAA sections 165(a) and 169(2)(C)). A ``major emitting
facility'' or ``major source'' is a stationary source that emits or
has the potential to emit (PTE) any air pollutant in the amount of
at least 100 or 250 tpy, depending on the source category and
irrespective of the facility's location. A major ``modification'' is
any physical or operational change to a stationary source that would
result in both a significant emissions increase and a significant
net emissions increase of one or more regulated NSR pollutants. A
new major source or major modification must apply BACT, which is
determined on a case-by-case basis taking into account, among other
factors, the cost effectiveness of the control and energy and
environmental impacts (40 CFR 52.21(b)(12) and (j)).
\27\ 40 CFR 52.21(b)(23); 40 CFR 52.21(m)(1)(i).
---------------------------------------------------------------------------

BOEM uses emission exemption thresholds to determine whether the
lessee's plan emissions would potentially impact the air quality of the
State. When the thresholds are not exceeded, those emissions are
presumed to not cause or contribute to an exceedance of the NAAQS. The
USEPA uses applicability thresholds to determine if a source is subject
to the requirements of the respective parts of the NSR permitting
program and then applies screening criteria like the SILs \28\ to
determine whether emissions per pollutant require further regulatory
review.
---------------------------------------------------------------------------

\28\ The SILs are benchmarks used by the USEPA to determine
whether some area may potentially be significantly affected by the
emissions generated from a proposed new stationary source of
emissions. The SILs are used as a screening tool to determine what
additional steps, if any, may be required before a stationary source
can be approved.
---------------------------------------------------------------------------

Given BOEM's distinct mandate to focus on State impacts from OCS
activities, BOEM currently uses a formula that accounts for the
distance of the facility from the shoreline. Specifically, the
determination as to whether a facility could significantly affect
onshore air quality under BOEM's AQRP is based on a formula that
considers both the amount of air pollutant emitted and the distance of
the proposed facility from the shoreline.\29\ Because BOEM's
determination of what constitutes potentially significant emissions
varies depending on a proposed facility's distance from shore, BOEM
uses distance as a variable in its formula to determine the relevant
EET. If a proposed plan would cause emissions of criteria or precursor
air pollutants in excess of the EET, the proposed plan is required to
include a detailed air quality analysis. If a proposed plan would not
cause emissions of criteria or precursor air pollutants in excess of
the EET, the plan is not required to include a detailed air quality
analysis. BOEM refers to plans that are not required to include a
detailed air quality analysis as ``exempt.''
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\29\ This differs from the way in which the USEPA determines
which facilities are subject to the NSR preconstruction permitting
program. As explained in the previous footnote, the USEPA makes this
determination based on whether the emissions of a new source or
modification to an existing source are higher than a certain amount
of tons of air pollution per year or whether the modification would
result in both a significant emissions increase and a significant
net emissions increase of one or more regulated NSR pollutants
irrespective of the facility's or facilities' location.
---------------------------------------------------------------------------

2. Exemption Threshold Analysis
The first step in the approach of both the current regulations and
the proposed rule is the exemption threshold analysis discussed above.
BOEM determines, based on the information provided by the lessee or
operator, whether or not any given plan (EP, DPP or DOCD) will generate
emissions above a defined exemption threshold. If so, further analysis
is required. If not, the impact to the air quality of the State is
presumed to be de minimis and no further action is required.
BOEM currently has only one set of exemption thresholds, which are,
under the existing regulations, applied identically in the Central and
Western GOM OCS Regions and offshore of the North Slope Borough of the
State of Alaska. BOEM is now in the process of conducting scientific
studies to re-evaluate the exemption thresholds formulas, for both the
GOM and Alaska OCS Regions to tailor those thresholds to the relevant
environmental characteristics of each region and to take into
consideration USEPA standards applied to various time periods, whether
annual or shorter intervals. These BOEM studies will evaluate and, if
necessary, provide the basis for updating the current exemption
threshold equations and consider whether recent advances in the field
of computer simulation modeling and the availability of comprehensive
meteorological datasets unique to each region may be applied to improve
the exemption threshold equations by applying the updated underlying
data. The studies will use computer-simulated air quality dispersion
and photochemical modeling to provide the information necessary to
evaluate the current threshold equations (i.e., for the EETs) and, if
necessary, establish a basis for developing a new method. All modeling
conducted for the studies will be consistent with the USEPA's Guideline
on Air Quality Models (40 CFR part 51 appendix W).
The GOM and Alaska OCS studies are designed to fulfill the
following objectives:

Prepare onshore and offshore emissions inventories for
use in computer simulation air quality dispersion and photochemical
modeling, based on the multi-sale 2017-2022 scenario emissions for
both OCS Regions;
Evaluate current meteorological data and develop new
data, as necessary, for input into air quality models;
Conduct air quality dispersion and photochemical
modeling to discern the collective effect of onshore and offshore
emissions on the onshore area of adjacent States;
Investigate the current exemption threshold formulas
for evidence the rates are protective of the annual and short-term
(24-hours or less) AAQSB using dispersion and photochemical air
quality modeling and, if necessary, develop a new method;

[[Page 19731]]

Conduct visibility analyses for the GOM Region Class I
areas: Breton Wilderness; Saint Marks Wilderness; Chassahowitzka
Wilderness; and Bradwell Bay; and,
Perform a 40 CFR part 51 appendix W section 3.2.2
``Equivalency Demonstration'' for modeling purposes in the GOM
region. Such an ``Equivalency Demonstration'' would involve
determining the most appropriate model for the exemption thresholds,
taking into account the USEPA list of preferred models and the
relevant criteria for evaluating alternatives.

As discussed above, BOEM is considering establishing two or more
sets of EETs (i.e., per pollutant, averaging time, and location), at
least one for the GOM OCS Region and at least one for the area offshore
of the North Slope Borough of the State of Alaska. For this reason,
BOEM would like comments on the appropriateness of potentially distinct
emissions thresholds or threshold formulas for these two areas, and/or
how these thresholds should be structured.
The USEPA recently established new one-hour NAAQS for
NO2, and SO2, as well as changes to the 8-hour
O3 and annual PM2.5 NAAQS, and also given that
the USEPA has recommended an interim SIL for one-hour NO2 at
8[mu]g/m³ \30\ and an interim SIL for one-hour
SO2 at 3 parts per billion,\31\ but has not proposed to add
these SILs (or any SILs for PM2.5 or ozone) to 40 CFR
51.165(b)(2), comments are solicited on how these new ambient standards
and SILs that have the status of only being USEPA recommendations
should be implemented in the context of the new studies, for the
purpose of updating the new EETs that result.
---------------------------------------------------------------------------

\30\ Available at: https://www3.epa.gov/nsr/documents/20100629no2guidance.pdf.
\31\ Available at https://www.epa.gov/sites/production/files/2015-07/documents/appwso2.pdf.
---------------------------------------------------------------------------

Until such time as new EETs are established, the existing exemption
thresholds will continue to apply identically in both regions.
3. Modeling Analysis
In the event the exemption threshold analysis indicates that one or
more criteria or major precursor pollutants would exceed an applicable
threshold, the plan submitter must proceed to the second step in the
BOEM AQRP, which is the modeling analysis. The purpose of the modeling
analysis is to help BOEM determine, based on the information provided
by the lessee or operator, whether or not the proposed operations that
generate emissions above an exemption threshold would cause or
contribute to a violation of the NAAQS.\32\ BOEM's AQRP currently
models the onshore concentrations created by the relevant criteria or
precursor pollutants emitted offshore. Under existing regulations,
plans that would result in operations or uses that generate ambient
concentrations above these Significance Levels as modeled onshore are
subject to further review and analysis. BOEM's Significance Levels are
listed in its regulations at 30 CFR 550.303(e).
---------------------------------------------------------------------------

\32\ Under this proposed rule, the modeling analysis would also
be used in certain cases to determine whether an exceedance of the
AAIs has occurred; this is not listed separately, since the purpose
of the AAI analysis is to protect an attainment area from
potentially exceeding the NAAQS.
---------------------------------------------------------------------------

These Significance Levels in BOEM's existing regulations are based
on USEPA's SILs (as they existed approximately 35 years ago), which are
ambient concentration levels used by the USEPA to determine whether the
ambient air concentration of any given air pollutant could cause or
contribute to a violation of the NAAQS at a given location. Under
USEPA's historical practice in the PSD program, if the ambient air
impacts of each criteria air pollutant are below the applicable SILs
for all relevant averaging times, then the incremental emissions are
considered to have an impact that is de minimis and, therefore, not
significant. BOEM's regulations utilize the USEPA's SILs to determine
whether emissions of any given pollutant that originates offshore could
have a potentially significant effect onshore. The USEPA SILs are
expressed in terms of pollutant concentrations averaged over a specific
period of time (i.e., averaging time), for example on an annual basis.
There are also SILs designed to evaluate peak emissions of air
pollutants over shorter time intervals, which include the 1-hour, 3-
hour, 8-hour, and 24-hour averaging times. By incorporating the
relevant USEPA values listed in a table in an USEPA regulation, BOEM
would automatically apply these timing intervals or averaging times, as
well for those pollutants and averaging times that are reflected in
USEPA regulations.
Under BOEM's existing regulations, in order to evaluate the
potential onshore effects of offshore emissions, the models project the
ambient concentration of any given air pollutant at various measurement
points onshore, which are referred to as receptor locations. If any
projected concentration of a given air pollutant does not exceed BOEM's
applicable Significance Level(s) at all receptor locations onshore for
all relevant averaging times, then the incremental emissions are
presumed de minimis, and no further analysis is required of emissions
of that pollutant under the BOEM AQRP. In other cases, additional
modeling and/or the application of relevant emissions reductions
measures will generally be required.
At the time the current BOEM regulations were promulgated, there
were no USEPA-approved modeling approaches to quantify the impacts of
single sources of volatile organic compound (VOC) emissions on ambient
O3 levels. For this reason, the current rule does not
require modeling of VOCs and there is nothing analogous to a SIL to
indicate ambient impact of VOCs. Instead of evaluating VOC emissions
against a SIL, VOCs are evaluated only against an exemption threshold.
CPs and the reductions in their emissions that may be required under
the current regulations are determined based on several different
levels that can vary with the location of the facility, the attainment
status of the areas it affects, and whether the facility is long- or
short-term. In contrast, in those situations where the emissions of
VOCs exceed the relevant emission exemption threshold, BOEM's
regulations instead require a reduction in the emissions of VOCs \33\
Based on the analysis done at the time, BOEM concluded that this
reduction should have been sufficient to address the potential impact
of VOCs on the formation of O3.\34\
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\33\ When VOC emissions exceed the EET for a short-term facility
or a long-term facility affecting only an attainment area, the
lessee or operator must apply ERM to reduce VOC emissions to the
greatest extent possible. For a long-term facility affecting a non-
attainment area, the lessee or operator must apply ERM to reduce VOC
emissions so that the EET is not exceeded.
\34\ Results of the ongoing studies in the GOM and Alaska will
provide an updated method for evaluating VOC contributions to
ambient ozone concentrations in the future.
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4. Controls for Short-Term Facilities
If it is determined through modeling that the planned operations
will generate an onshore concentration of one or more air pollutants in
excess of the SILs, various further analyses must be done in order to
determine what controls must be applied. Under the current AQRP, if a
facility is projected to cause ambient concentrations of air pollution
above acceptable levels (i.e., the SILs), the lessee or operator of
that facility must propose the application of BACT \35\ in connection
with post-control modeling, to demonstrate the AAQSB will likely be
met. The requirements applicable to making this determination

[[Page 19732]]

vary depending on the amount of time that the facility described in the
proposed plan is anticipated to be present at any given location. The
current regulations make a distinction between temporary and permanent
facilities. Under the proposed rule, the phrase ``short-term facility''
is used instead of the phrase ``temporary facility.'' In both cases,
these terms refer to a facility that is located in one place for less
than three years.
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\35\ In this proposed rule, references to BACT are intended to
refer to BOEM's current or proposed requirements, unless the USEPA's
definition is specifically referenced. Under the USEPA regulations,
most types of ERM could qualify as BACT, whereas BOEM's definition
is substantially limited to physical or mechanical controls.
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Under the proposed rule, if the projected concentration increase
due to emissions from the proposed short-term facility exceeds the SILs
but such exceedance only affects attainment areas, the lessee or
operator would be required to determine the maximum amount of emissions
reductions that it can achieve with operational controls and/or
equipment replacements that are technically and economically feasible.
This would represent a level of emissions reductions that achieves the
maximum efficiency of their operations with respect to emissions
reduction. At that point, the lessee or operator could decide whether
to apply those operational controls and/or equipment replacements, or
to instead obtain emissions credits. If it is determined that there are
no operational controls and/or equipment replacements that are
technically and economically feasible, and the emissions from the
proposed facility would affect only attainment areas, then no ERM would
be required. In BOEM's proposed rule, a maintenance area is treated as
an attainment area; thus, the same requirements would apply.
If the projected emissions for the proposed short-term facility
exceed the SILs and such exceedance would affect a designated non-
attainment area, the lessee or operator would not only be required to
conduct an ERM analysis, but might also be required by the Regional
Supervisor to apply additional types of ERM (beyond that which was
proposed in the original plan).
Under the proposed rule, described in more detail in the section-
by-section analysis for section 550.306, a process has been outlined to
facilitate the determination of the most appropriate ERM, of which BACT
is one option. If the lessee or operator proposes to use BACT, the
lessee or operator would be required to provide a description of the
associated energy, environmental and economic impacts,\36\ and other
costs.
---------------------------------------------------------------------------

\36\ The description of the associated energy, environmental and
economic impacts is not required in the case of non-BACT ERM.
---------------------------------------------------------------------------

In the case of a short-term facility, the application of ERM would
generally be sufficient for BOEM to conclude, without further analysis,
that the facility does not cause a significant effect on the air
quality of a State. As explained in the next Section, this presumption
would not apply in the case of a long-term facility. Although BOEM
would set the air emissions limits in connection with its approval of
the plan, BSEE would be responsible for ensuring that any required ERM,
including BACT, are actually applied in compliance with the plan
requirements.
5. Controls for Long-Term Facilities
If emissions from a long-term facility generate onshore
concentrations of air pollutants in excess of the SILs, under the
current regulations, the lessee or operator must apply BACT. If only an
attainment area is affected, the proposed BACT must result in the plan
or facility meeting the Maximum Allowable Concentration Increases
(MACIs), which are set out in a table in BOEM's regulations. The MACIs
are based on the USEPA's AAIs, and are designed to prevent the air
quality in clean areas from deteriorating to an unacceptable level as
set by the NAAQS. The NAAQS represent a maximum allowable concentration
``ceiling'' for each air pollutant and averaging time that does not
vary geographically. A MACI, on the other hand, represents the maximum
increase in concentration that is allowed to occur above a baseline
concentration for any given pollutant. Baseline concentrations vary
geographically. When the MACI \37\ is added to the baseline
concentration, the result is a new ``ceiling'' specific to that area. A
significant deterioration in the air quality is said to occur when the
concentration of a pollutant would exceed the applicable MACI added to
the baseline concentration in that area. BOEM and its predecessors have
taken the position that the exceedance of a MACI constitutes a
significant deterioration in air quality that ``significantly affect[s]
the air quality of any State.'' Moreover, the MACIs are designed to
ensure that attainment areas do not fall out of attainment, and so they
are appropriate increments to ``ensure compliance with the [NAAQS].''
Thus an activity that has the potential to cause an exceedance of the
MACIs should not be approved under BOEM's current regulations.
---------------------------------------------------------------------------

\37\ Under BOEM's current regulations, the term MACI is used.
This proposed rule would eliminate that term and use the term AAI
exclusively.
---------------------------------------------------------------------------

These MACIs, and the AAIs on which they were based, vary depending
on whether any given location is defined as a Class I, a Class II or
Class III location (described below in the discussion of the
definitions of those terms) and the relevant timeframes of exposure
(i.e., averaging times).
Under the proposed rule, with respect to impacts in an attainment
area, if emissions from a long-term facility were to generate
concentrations of air pollutants landward of the SSB in excess of the
SILs, the lessee or operator would be required to undertake an ERM
analysis, excluding BACT, to determine the most effective and
technically and economically feasible approach for reducing the
projected emissions from its facility. If the projected concentration
increase due to emissions from the proposed facility exceed the SILs
but do not exceed the AAIs, the proposed plan could be approved without
the lessee or operator having to bring the concentration increase due
to the emissions from its operations below the SILs. If the projected
emissions exceed the AAIs after the application of ERM, the lessee or
operator would be required to use additional ERM until it could
demonstrate its emissions no longer resulted in such an exceedance.
Under the proposed rule, with respect to impacts in a non-
attainment area, if emissions from a long-term facility were to
generate concentrations of air pollutants landward of the SSB in excess
of the SILs, the lessee or operator would be required to undertake an
ERM analysis, including BACT, to determine the most environmentally
effective of the technically and economically feasible approaches for
reducing the projected emissions from its facility. If the projected
concentration increase--due to emissions from the proposed facility--
continue to exceed the SILs after the application of ERM, the proposed
plan could not be approved without the lessee or operator having to
bring the concentration increase due to emissions from its operations
below the SILs. Regardless of whether the projected emissions would
affect a designated non-attainment or attainment area, the lessee or
operator would be free to propose emissions credits in lieu of any
other ERM to accomplish this objective.
The proposed rule retains a requirement in the current regulations
(in 30 CFR 550.303(g)(2)(i)(B)) that no plan can be approved if that
plan would result in the generation of emissions sufficient to cause an
area of a State to switch from attainment to a non-attainment status.
For that reason, any long-term facility that demonstrates projected
emissions in excess of the SILs would be required to demonstrate that
those emissions do not cause the

[[Page 19733]]

exceedance of any NAAQS in an attainment area.
6. Protection of Exceptional Natural Resources
As part of the 1977 amendments to the CAA (Pub. L. 95-95; 91 Stat.
685), Congress mandated that the country be divided into various areas
based on their sensitivity to potential problems associated with poor
air quality. These amendments establish Class I, II, and III areas. The
restriction on emissions are most strict in Class I areas and are
progressively more lenient in Class II and III areas. In addition to
the three classifications mentioned in the statute, the Federal Land
Managers (FLMs) \38\ have established a fourth classification which
they title ``sensitive Class II areas.'' Sensitive Class II areas
represent an intermediate classification intended to designate special
areas, such as national monuments and national refuges that, while not
subject to the same level of controls as Class I areas, require special
protections above those normally afforded to typical Class II areas.
---------------------------------------------------------------------------

\38\ The Federal Land Managers' Air Quality Related Values Work
Group (FLAG) was formed to develop a more consistent approach for
the Federal Land Managers (FLMs) to evaluate air pollution effects
on their resources. Of particular importance is the New Source
Review (NSR) program, especially in the review of Prevention of
Significant Deterioration (PSD) of air quality permit applications.
For a facility located in or near a Class I area, the PSD permitting
program uses AQRVs when evaluating the potential impact of a
proposed source or modification on resources which are sensitive to
air quality.
---------------------------------------------------------------------------

Thus, parts of the country are designated as Class I or sensitive
Class II areas to indicate that they have been identified for special
protections. National parks, national wilderness areas, national
monuments, national seashores, and other areas of special national or
regional natural, recreational, scenic, or historic value are generally
designated as Class I \39\ or as sensitive Class II areas. FLMs,
including the U.S. Department of Agriculture's Forest Service, and
DOI's Bureau of Land Management (BLM), National Park Service (NPS) and
U.S. Fish and Wildlife Service (FWS) manage these areas. Together,
these FLMs have the affirmative responsibility to protect the unique
attributes and air quality of Class I and sensitive Class II areas.
BOEM has not proposed and does not intend to evaluate air quality
impacts in non-sensitive Class II or Class III areas other than by
applying the typical AQRP requirements.
---------------------------------------------------------------------------

\39\ Several tribes have also requested USEPA to redesignate
their lands from Class II to Class I to provide additional air
quality protection. These are the Northern Cheyenne Reservation, the
Flathead Indian Reservation, the Fort Peck Indian Reservation, the
Spokane Indian Reservation and the Forest County Potawatomi
Community Reservation. See 40 CFR 52.1382(c), 52.2497(c) and
52.2581(f).
---------------------------------------------------------------------------

Under the CAA, FLMs are charged with reviewing available
information about proposed facilities in order to determine their
potential air quality impacts on Class I areas. FLMs have established
Air Quality Related Values (AQRV), which represent resources which are
sensitive to air quality and include a wide array of vegetation, soils,
water, fish and wildlife, and visibility. The goal of the FLMs is to
ensure that pollution levels stay below the critical loads (i.e., below
which they have determined there would be no adverse impact to a Class
I area). These AQRVs include values designed to protect visibility,
odor, flora, fauna, and geological, archeological, historical, and
cultural resources, as well as soil and water resources. The AQRVs for
various Class I areas differ depending on the purpose and
characteristics of a particular area and the assessment by an area's
FLM. The FLMs determine the requirements for compliance with each
AQRV.\40\
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\40\ See https://www.nature.nps.gov/air/Pubs/pdf/flag/FLAG_2010.pdf.
---------------------------------------------------------------------------

FLMs evaluate plans submitted to BOEM to determine whether there
would be any potential adverse impact to a Class I or sensitive Class
II area and to recommend controls, as appropriate, if there are
potentially adverse impacts. In order to complement this process,
BOEM's AQRP requires any proposed long-term facility whose emissions
cause an exceedance of the SILs to meet the standards for the MACIs
that correspond to the Class designation of the areas onshore of the
proposed operations.
7. Primary and Secondary National Ambient Air Quality Standards (NAAQS)
Evaluation
Once BOEM determines the MACIs or the SILs would not be exceeded,
BOEM must make a further determination that the NAAQS would also not be
exceeded in any attainment area.
There are two types of NAAQS, primary and secondary. Primary NAAQS
are intended to protect public health, including the health of
sensitive subpopulations with a requisite margin of safety, whereas
secondary standards are intended to protect public welfare (e.g.,
effects on crop yields) from any known or anticipated adverse effects
associated with the presence of the specified pollutants in ambient
air. These standards are composed of four elements: Indicator;
averaging time; statistical form; and level. Under both BOEM's current
regulations and its proposed rule, for any pollutant for which there is
more than one standard, plans must comply with whichever NAAQS standard
is strictest in terms of the ERMs needed for the facility. Generally,
according to both BOEM and USEPA regulations, no project can be
approved if it would result in design concentrations for any given air
pollutant in excess of the level for either the primary or secondary
NAAQS for that pollutant in an attainment area.
The NAAQS, codified at 40 CFR part 50, identify the maximum
allowable concentrations, or ``ceilings,'' and forms, for each of the
various CPs at any given location. Under its current regulations, BOEM
will not approve a plan that it determines would cause the ambient air
quality either at the shoreline or farther onshore to deteriorate
significantly beyond the air quality specified by the applicable NAAQS
for any given air pollutant, regardless of whether the change would
comply with the other relevant SIL(s) or AAI(s) for that same
pollutant.\41\ Because the NAAQS represent the amount of an air
pollutant that is allowable at any given location, evaluating the
emissions of the pollutant to determine the potential for an exceedance
requires information on existing concentrations of the pollutant at the
location, i.e., the background concentration. The sum of the background
concentration of the pollutant plus the incremental concentration of
that same pollutant caused by the projected emissions for the relevant
averaging time and statistical form is referred to as the design
concentration of that pollutant. BOEM compares the design concentration
with the NAAQS to determine if there is likely to be an exceedance.
---------------------------------------------------------------------------

\41\ There could be an exception in a case where offsets are
used in lieu of another ERM. In the proposed rule, the emissions
credits must affect the same Air Quality Control Region (AQCR) as
the facility's projected emissions. Because the boundaries of the
AQCR may not be the same as the boundaries of the non-attainment
areas (because non-attainment areas are typically much smaller), and
because the proposed rule would commit BOEM to always allowing
offsets provided they are in the same AQCR, the effects of the
facility's pollution and the offsets may occur in different areas.
Thus, it is possible that the non-attainment area may remain
unaffected even after the relevant ERM have been applied. Since the
offset is the same magnitude as the required reduction, the
statement would be accurate on an aggregate basis, regardless of the
attainment/non-attainment areas to which the offset would apply.
---------------------------------------------------------------------------

8. Intersection With the National Environmental Policy Act
Under current BOEM regulations, while the AQRP is focused on the
extent

[[Page 19734]]

to which projected air emissions generated offshore could significantly
impact the air quality onshore, BOEM also considers air quality impacts
related to lease and plan approval as part of its analyses conducted
pursuant to NEPA. BOEM considers potential impacts from air emissions
individually and collectively, including potential air quality impacts
offshore and onshore that would be caused by proposed oil and gas
exploration and development activities. Because of BOEM's staged
decision-making with respect to activities conducted under an OCS
lease, NEPA reviews involve multiple analyses and occur at several time
points in the OCS lease and development process.
In order to comply with the applicable requirements of NEPA, BOEM
evaluates the likely cumulative impacts of OCS development during its
Five-Year Oil and Gas Leasing Program and the associated Five-Year
Programmatic Environmental Impact Statement. BOEM conducts an
additional analysis of such prospective impacts at the time it prepares
a multi-sale Environmental Impact Statement (EIS) or a NEPA analysis on
an individual lease sale. BOEM conducts an even more detailed air
quality analysis at the time the lessee or operator submits the EP, or
RUE or ROW application, lease-term pipeline application, and again when
the lessee or operator submits a DPP or DOCD. At these two later
stages, BOEM conducts the AQRP in order to ensure the lessee's or
operator's implementation proposals comply with the applicable
requirements of OCSLA and the corresponding BOEM regulations.
9. Additional Environmental Review
BOEM conducts analyses of the potential impact of OCS development
on the conservation of the natural resources of the OCS and overlying
waters (including the fish, marine mammals, plants, corals, etc.) to
ensure the prevention of waste; to evaluate those circumstances that
could result in environmental and other hazards; and to conserve and
protect the associated mineral, economic, and environmental resources
in and over the OCS, in accordance with OCSLA at 43 U.S.C. 1334(a),
1340(c), and 1351. Current BOEM regulations also specify each Regional
Supervisor should evaluate every plan and make a determination that the
proposed activities will not cause serious harm or damage to the
marine, coastal, or human environment (e.g., 30 CFR 550.202).

E. Conclusion

BOEM's AQRP is intended to protect the air quality of the States
and to achieve the following objectives with regard to OCS exploration
and development: (1) To protect public health from adverse effects; (2)
to protect public welfare, including the economies of the States, by
preventing a deterioration in the air quality of the environment (e.g.,
to protect crops, forests, and wildlife); (3) to prevent the formation
of new designated non-attainment areas; and (4) to preserve and enhance
the air quality in national parks and other areas of special natural,
recreational, scenic, or historic value. BOEM continues to maintain
these same goals and objectives as it proposes to amend the regulations
to more effectively meet these goals and objectives. In most cases,
these objectives are similar to those of corresponding analysis and
permit review processes of the States, working in conjunction with the
USEPA.
In addition to BOEM's AQRP, the Bureau of Safety and Environmental
Enforcement (BSEE) has an enforcement program designed to ensure
lessees and operators comply with BOEM's air quality regulations and
that such lessees and operators do not emit air pollutants that exceed
the terms of their approved plans or RUE or pipeline ROW applications.
BOEM provides plan information to BSEE on a regular basis, and BSEE
uses this information to evaluate applications for permits to drill.
BSEE also monitors lessee or operator operations on an ongoing basis,
as one component of its inspections process.

IV. Summary of Key Changes

A. Air Pollution Emissions Standards

The current rule has AAQSB relevant to CO, SO2,
NOX, total suspended particulates (TSPs) and VOCs. The
proposed rule would broaden the scope of BOEM's AQRP to cover all the
NAAQS criteria pollutants and the major precursor pollutants, as
required by OCSLA. Under the proposed rule, carbon monoxide and VOCs
would be subject to substantially the same requirements as under the
current regulations. The review of SO2 would be expanded to
also include an evaluation of other sulphur oxides (SOX).
Total suspended particulates would be replaced as an indicator
pollutant with a new indicator pollutant titled PM10. New
regulatory requirements would be added for O3, Pb,
PM2.5, and NH3, none of which have specific
emissions limits in the current regulations. In addition, the
requirements for hydrogen sulfide (H2S), a minor precursor
to SO2, would be refined. The proposed rule defines BOEM's
list of criteria and precursor pollutants by reference to the relevant
tables in the USEPA's regulations, thereby ensuring that any changes or
additions promulgated by the USEPA would be automatically accounted for
in the BOEM regulations.
In addition to accounting for all of the criteria and major
precursor pollutants, as required by OCSLA, the proposed rule would
result in enhanced collection, evaluation, and consideration of data on
such pollutants over a greater variety of time intervals (i.e.,
averaging times), because BOEM would evaluate air pollutant emissions
in terms of the effects, not only on annual pollution levels, but also
on pollution levels for the other averaging times the USEPA uses in
evaluating SILs, AAIs (MACIs) and NAAQS for CPs, including 1-hour, 3-
hour, 8-hour, and 24-hour averaging times. The differing averaging
times were established in recognition that higher short-term
concentrations of a pollutant can have adverse effects even when the
long-term average concentration of the same pollutant falls within
relevant annual standards. The proposed rule would better align and
coordinate the information gathering and data analysis requirements in
BOEM's regulations with similar requirements used by the USEPA and
reflected in USEPA requirements and tables. Specifically, under the
proposed rule, BOEM would require the use of the USEPA's tables for
SILs, AAIs and NAAQS in any circumstance where modeling is required.
Thus, any changes to any applicable USEPA AAQSB would automatically be
cross-referenced by BOEM regulations and would not require that BOEM
amend or update its regulations.
Under the proposed regulations, certain provisions within BOEM's
rules would be updated automatically whenever the USEPA makes
corresponding changes in:

The SILs, also known as significant impact levels or
significance levels, with the associated averaging times, as defined
in 40 CFR 51.165(b)(2);
The AAIs (i.e., concentration levels of ambient
pollutants and associated statistical form), as defined in 40 CFR
52.21(c);
The primary or secondary NAAQS, as defined in 40 CFR
part 50;
The identification of criteria and major precursor air
pollutants, as defined in 40 CFR 51.15(a);
The list of approved air quality models, as defined in
40 CFR part 51, appendix W;
USEPA air quality modeling requirements and
methodologies, as defined in 40 CFR part 51, appendix W;

[[Page 19735]]

Emissions factors, based on models defined by the USEPA
or the FAA, to determine emissions levels for tier- and non-tier-
compliant marine and non-road engines and aircraft;
Reporting timeframes associated with the NEI; and
Significant emissions rates (SERs) for criteria and
major precursor pollutants, as defined in 40 CFR 51.21(b)(23)(i).

Under the proposed rule, certain provisions in BOEM's rule would
also be updated automatically whenever the USEPA changes 40 CFR
1043.100 to reflect emissions standards and other requirements
applicable to marine engines under Annex VI to the International
Convention for the Prevention of Pollution from Ships (as the protocol
is defined in 33 U.S.C. 1901), as implemented in the U.S. through the
Act to Prevent Pollution from Ships (33 U.S.C. 1901-1915). This
protocol is commonly referred to as ``MARPOL.'' The MARPOL standards
are part of the federal coordinated strategy to address emissions from
vessels adopted by the USEPA which consists of (1) the CAA engine
standards and fuel limits for U.S. vessels contained in 40 CFR 80 and
40 CFR 1042; (2) the North American and U.S. Caribbean Sea Emission
Control Areas designed by amendment to the MARPOL protocol; and (3) the
MARPOL engine emission and fuel sulphur limits that apply to all
vessels regardless of flag (see 75 FR 22896, April 30, 2010). BOEM
proposes that foreign vessels be allowed to use the MARPOL standards as
emission factors for the purposes of the program, if there are no
preferred, more accurate alternatives, with certain adjustments.\42\ In
addition, as the following are modified by the USEPA, BOEM's standards
for review of plans and requirements would change correspondingly:
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\42\ Such adjustment would be done in order to take appropriate
account the deterioration in performance, based on the age of the
equipment and the potential variation of the actual emissions from
the standard to account for the maximum potential emissions that the
emissions source may emit (as described in section
550.205(b)(2)(vii) of the proposed rule text).

The attainment or designated non-attainment status of
State lands potentially impacted by emissions from OCS activities,
as defined in 40 CFR part 81, subpart C; and
The Class designation of federal, State or tribal lands
or waters on or potentially impacted by emissions from OCS
activities, as defined in 40 CFR part 81, subpart D.

B. Attributed Emissions

Historically, BOEM has considered two primary sources of emissions
in connection with its regulation of OCS air emissions--stationary
sources, and non-stationary sources, such as support vessels, over-the-
ice vehicles and aircraft. The proposed rule would change the manner in
which lessees and operators must consider and model emissions from
support vessels and other non-stationary sources. The changes would
mean that plans will more accurately reflect how emissions may affect
the air quality of States, given improvements in modeling capabilities.
1. Emissions From Stationary Sources
BOEM proposes relatively few changes to what constitutes the kinds
of stationary sources of air emissions subject to review and/or
regulation. In accordance with OCSLA, all offshore facilities
constructed or operating on the OCS must be covered by an approved plan
that BOEM has evaluated for compliance with relevant emissions
standards. While the proposed rule would retain this basic principle,
the proposed rule would expand the definition of facility to address
the greater variety of facilities now being constructed. Accordingly,
the proposed rule would replace any existing reference to a ``drilling
unit'' with a reference to the broader term ``facility'' and would
clarify that air quality and air emissions information and analysis
must be provided with respect to any facility that is proposed to be
located on the OCS. Further details concerning the definition of the
term facility are provided in the section-by-section analysis of the
new or updated definitions listed in section 550.302. The proposed rule
would make clear that emissions from decommissioning activities would
be included in a facility's projected emissions.
This proposed rule does not specify air quality review requirements
associated with the decommissioning or removal of structures on the
OCS. BOEM is soliciting information on the most appropriate method for
establishing and reporting air quality requirements associated with
decommissioning and structure removal activities in the context of the
AQRP. This includes a request for information and comment on when and
how BOEM should receive air quality emission data and information
associated with decommissioning and structure removal and how an
assessment of feasible ERM should be applied. One approach on which
BOEM solicits comment would be whether it should provide for only the
collection of emissions data associated with decommissioning activities
for some period of time, followed by a second phase in which BOEM could
utilize the data that was previously collected to craft an approach
tailored to this unique type of activity.
2. Emissions From Mobile Support Craft (MSC)
In the proposed rule, BOEM would continue to require the collection
and evaluation of emissions data related to offshore supply vessels
(OSVs) and other support vessels and vehicles (collectively, mobile
support craft (MSCs)) for two primary reasons. First, the data remain
necessary to accurately model the impact of any given exploration or
development project to determine whether the air emissions are likely
to exceed the emissions thresholds, and, therefore, to determine
whether the air emissions are potentially significant. Second, this
proposed rule would allow BOEM to use the data to determine whether
emissions associated with a project covered by a plan are at a level
such that the planned operations could cause or contribute to a
violation of the NAAQS in a State.
BOEM's statutory responsibility to regulate ``for compliance with
the [NAAQS], to the extent that activities authorized under this
subchapter significantly affect the air quality of any State,''
authorizes BOEM to take into account sources of emissions directly
related to OCS operations that have the potential to significantly
affect a State's air quality.\43\ A portion of the emissions associated
with exploration and development of OCS oil and gas come from the MSCs
providing support to OCS operations. While MSC operations do not
require direct BOEM authorization, their activities and the associated
emissions are undertaken pursuant to contracts and orders from lessees
and operators engaging in oil and gas exploration and development,
which require BOEM's approval of a plan. Without an accounting of these
emissions in the plan, BOEM would not know whether emissions that will
stem

[[Page 19736]]

from its approval would have the potential to significantly affect the
air quality of any State. Accordingly, BOEM is not proposing to
regulate MSC sources directly, but it would continue its current
practice of attributing MSC emissions to the approved facilities that
the MSCs support. The most feasible, and perhaps only means, of
preventing significant effects on State air quality is to require
operators to manage the emissions that are closely associated with its
operations. In this rule BOEM is proposing to refine the method for
attributing these mobile source emissions to facilities.
---------------------------------------------------------------------------

\43\ The conference report accompanying the enactment of section
5(a)(8) of OCSLA explained:
The standards of applicability the conferees intended the
Secretary to incorporate in such regulations is that when a
determination is made that offshore operations may have or are
having a significant effect on the air quality of an adjacent
onshore area, and may prevent or are preventing the attainment or
maintenance of the AAQSs of such area, regulations are to be
promulgated to assure that offshore operations conducted pursuant to
this act do not prevent the attainment or maintenance of those
standards. The terms ``may have'' and ``may prevent'' refer to the
Secretarial judgment regarding future consideration of exploration
plans, or development and production plans, in which the potential
for ``significant effect'' is analyzed prior to approval and thus
commencement of the proposed activities.
See, H.R. Rep. No. 95-1474, at 85-86 (1978) (Conf. Rep.).
---------------------------------------------------------------------------

Historically, and with cooperation from industry, BOEM followed an
approach similar to the USEPA's to account for vessel emissions in the
GOM. BOEM's current regulations require that operators report in their
plans those emissions from MSCs that occur within 25 miles of a OCS
facility. Although the current regulations are not explicit on this
point, BOEM's GOM practice has been to add these emissions to the
emissions of the facility and compare the total against the exemption
thresholds to determine whether modeling and controls are required.\44\
BOEM's predecessor agencies chose this approach to be consistent with
the approach used by the USEPA.\45\
---------------------------------------------------------------------------

\44\ The practice has differed in BOEM's Alaska region during
those periods in which the Secretary had air quality jurisdiction
over the Arctic OCS. For the Arctic, BOEM's practice has been to
require reporting of MSC emissions in the plan, but the Alaska
region has not made it a practice to combine those emissions with
the facility's emissions to compare against the exemption
thresholds.
\45\ See sec. 328 of the CAA, 43 U.S.C. 7627, specifies that
``emissions from any vessel servicing or associated with an OCS
source, including emissions while at the OCS source or en route to
or from the OCS source within 25 miles of the OCS source, shall be
considered direct emissions from the OCS source.'' OCLSA does not
mention emissions from such vessels.
---------------------------------------------------------------------------

However there are a number of reasons that attributing all MSC
emissions within a 25-mile radius of the facility may not be the best
approach. This method of attributing emissions does not provide the
most accurate picture of the effects of BOEM's plan approval on the
State's air quality. Historically, the vast majority of new OCS
operations were located within 50 miles of the shoreline. Thus, the 25-
mile facility radius adequately addressed the impact of vessel air
emissions on the air quality of States. For facilities located within
25 miles of the shoreline, 100% of all MSC emissions would have been
accounted for by this formula. For facilities located 50 miles from the
shoreline, roughly 50% of the total MSC emissions would have been
accounted for. For facilities located 100 miles from the shoreline,
only 25% of the total MSC emissions would be accounted for and at 200
miles distance, only 12.5% of the emissions would be considered. Also,
in terms of the potential impact to a State, the most important MSC
emissions generally would be those occurring closest to the State.
Therefore, although 25% of MSC emissions for a facility located 100
miles from shore may be accounted for under the 25-mile rule, the 75%
of emissions that are not considered would likely have a greater
impact. According to the formula used in BOEM's current exemption
thresholds, 3,300 tons of emissions 100 miles from shore would have an
equivalent effect to 100 tons of emissions of the same pollutant 3
miles from shore. Applying this formula, the 25% of emissions within 25
miles of a facility would account for less than 2% of the impact on
State air quality, and the portion of emissions from MSCs that occur
while the MSC is closer to the State's boundary would have a
proportionally larger effect on the State's air.
Historically, facilities in the GOM accounted for the vast majority
of the total emissions, with MSC emissions representing only a small
share of total emissions. However, in the most recent inventory, BOEM
determined that facilities only account for 45% of all OCS emissions
associated with oil and gas exploration and production. Also, today,
more facilities are being constructed at increasing distances from the
shoreline. Today, some are located as far as 200 miles away from shore.
Given these shifts, BOEM believes it is no longer appropriate to
utilize a blanket 25-mile radius, because that radius does not capture
most of the attributed emissions that occur between a port and the
facility. Thus, the importance of accurately taking MSC emissions into
consideration has grown substantially. BOEM could not ensure that it
has avoided permitting uses of the OCS that would adversely affect the
State if its evaluation of OCS projects did not take into account the
majority of the relevant emissions.
Additionally, current BOEM analysis treats all emissions from MSCs
as if they originate at the facility itself. Improvements in dispersion
modeling technology have made it easier to more accurately project
impacts of emissions based on where these emissions actually occur. For
this reason, it is no longer necessary or appropriate to aggregate
emissions from non-stationary sources at one location for purposes of
air quality analysis.
Increasingly, lessees and operators are using new types of support
vessels, including vessels that operate continuously offshore without
having to return to port. When considered along with those support
vessels that are unique to the Arctic, either due to its extreme
environmental conditions or to the need to make up for the lack of
onshore support facilities, it is increasingly evident that the use and
types of vessels are substantially different than in the past.
In the Consolidated Appropriations Act, 2012 (Pub. L. 112-74),
Congress mandated that BOEM regulate air quality impacts from
activities on the OCS adjacent to the North Slope Borough of the State
of Alaska along with activities on the OCS in the Central and Western
GOM. BOEM must now also consider the potential effects caused by air
pollution generated by operations unique to the Arctic region, such as
ice breakers and other vessels or vehicles that would not normally be
necessary or present in the GOM. The relative proportion of attributed
emissions to total emissions (i.e., support vessel emissions relative
to facility emissions) is substantially higher in Alaska than in the
GOM. This is due to, among several things, the substantial differences
in the existing oil and gas infrastructure, the significant variations
in climate between the GOM region and Alaska, and the relatively
greater need for MSCs (and their higher emissions) to support OCS
facilities offshore Alaska. In the Alaska region, a typical ratio of
MSC emissions to facility emissions would be in the range of 80% to
20%. Thus, the emissions of ice breakers, oil spill support vessels,
trucks that operate over ice and other vessels unique to the Arctic
make the need to account for MSC emissions even greater than is the
case in the GOM.
Furthermore, those MSCs used in Alaska are of a type whereby they
can more readily operate outside of a 25-mile radius of the facility.
While supply vessels, crew boats and tug boats cannot easily avoid
coming into close contact with the facility they support, this is not
true of ice breakers or oil spill support vessels. Such vessels can be
and often are located just beyond the 25-mile boundary, sometimes
closer to shore than the facility itself. Because, in an Arctic
context, the MSCs generate far more emissions than the facilities they
support, not accounting for their emissions makes it impossible to
appropriately avoid authorizing activity causing or contributing to a
violation of the NAAQS.
BOEM is proposing a more accurate standard, namely that the
emissions of MSCs should be accounted for while they are actually
operating in support of

[[Page 19737]]

the facility. As long as an ice breaker is engaged in active operations
on behalf of a facility (and, in whose absence, the ice breaker would
not be used), its emissions should count towards the total emissions
resulting from plan approval. Once the MSC is no longer providing
support to a facility, its emissions should not be considered as part
of the projected emissions in the plan.
In addition to these differences, technological advances with
respect to non-stationary source modeling allow more accurate modeling
of emissions from non-stationary sources. Unlike the situation in the
past, when there was no accurate means to evaluate the emissions of
mobile sources in terms of the impact to stationary sources, such
modeling can be readily and accurately done today. BOEM believes that
it is important to employ the most advanced and scientifically accurate
measurements and evaluation techniques of air pollution, in order to
most effectively implement its mandate.
For all these reasons, BOEM has reevaluated its historical method
of accounting for non-stationary source emissions (i.e., emissions
generated from support vessels, vehicles, and aircraft operating on the
OCS, or in State waters, that are associated with OCS facilities) and
proposes to revise the current practice in both Alaska and the GOM to
better address BOEM's mandate. Instead of automatically applying a 25-
mile radius, BOEM is proposing to require lessees and operators to
report and attribute the MSCs to facilities to which the vessel is
actually providing operational support, regardless of its distance from
that facility. In the proposed rule, the key is whether an MSC is
operating in support of a facility authorized under OCSLA, not how
close the MSC it is to that facility. The proposed rule would require
all MSCs operating in support of a facility to attribute their
emissions to that facility while they provide such support (except in
those rare cases where such attribution would be impractical). MSCs
that do not provide support to a facility would not be reported,
regardless of how close or distant they are. The discussion of proposed
Sec. 550.205(d), in the section-by-section description below, sets
forth the details of how the proposed rule would require lessees and
operators to attribute MSC emissions to a facility, including the
allocation of emissions from MSCs servicing multiple facilities (see
discussion below).
3. Determination of Attributed Emissions
BOEM is proposing to define the term ``attributed emissions'' to
cover non-stationary source emissions associated with a plan,
including, ``for any given criteria or precursor air pollutant, the
emissions from MSCs and aircraft, operating above the OCS or State
submerged lands, that are attributed to a facility.''
As described in the discussion of proposed Sec. 550.205(d), in
section V below, where an MSC described in a plan also supports one or
more facilities not described in a plan, the proposed rule would
provide several alternatives for determining the emissions from a
vessel or vehicle that should be attributed to the particular facility
in the plan. A lessee or operator could always choose to attribute all
of an MSC's emissions to a facility regardless of how many facilities
it supports. The rule, however, would allow a lessee or operator to
attribute only that relevant portion of a vessel's emissions to its
facility or facilities. The proposed rule would provide a lessee or
operator with a process to attribute only a portion of an MSC's
emissions to its facility. This procedure is designed to provide the
most detailed, accurate information available about the MSC's
emissions. BOEM recognizes that any given lessee or operator may not
know at the time of plan submittal, or RUE or pipeline ROW application,
the extent to which it will rely on MSCs that also support facilities
unrelated to those covered by the lessee's or operator's plan. For this
reason, the procedure would allow lessees and operators alternative
ways of making conservative estimates of the portion of an MSC's
emissions that should be attributed to a facility. The intent of these
alternatives is to simplify the process for determining the allocation
of support vessel emissions in situations where it would otherwise be
impracticable to do so.
BOEM's proposed approach would reduce the potential for over-
counting emissions resulting from plan approval compared with BOEM's
current practice. Under BOEM's current practice, one hundred percent of
the emissions of an MSC are counted when located within 25 miles of a
plan facility, regardless of whether that MSC also supports five, ten,
or even 20 unrelated facilities within a 25-mile radius of the
facility. Under the proposed rule, emissions would be allocated to the
appropriate facility in all cases where it would be practicable to do
so, in accordance with proposed Sec. 550.205(d). Only in the rare
situation where there would be no reasonable basis to make any more
accurate allocation would the 25-mile radius analysis remain as a last
resort option. Ultimately, BOEM believes there is no reason to hold an
operator responsible for emissions based on an emitting MSC's proximity
to a facility, but rather it should be required to manage its
operations to prevent exceedances of the NAAQS which result from only
those MSCs which actually support its operations. Air emissions of an
MSC may often occur close to shore, and therefore would cause a greater
impact onshore and/or at the SSB, than a similar amount of emissions
from that same MSC which occur in the vicinity of the facility. BOEM is
seeking comments on this proposed approach and will consider
alternative methods that more accurately attribute emissions from
mobile sources to the appropriate facility.
4. Exclusion of Aircraft and Onshore Emissions Sources
BOEM also proposes to change its approach to accounting for air
pollutant emissions associated with other non-stationary sources. The
proposed rule would continue to require lessees or operators to
identify all vessels and vehicles supporting a facility and to report
their relevant air emissions as part of each plan, as is the case with
the current policy. However, BOEM is proposing to change how aircraft
and onshore emissions would be addressed.
Although lessees or operators would continue to be required to
identify the likely types and number of support aircraft they propose
to use, no collection of emissions data for those aircraft would
generally be required under the proposed rule, except in exceptional
circumstances. BOEM is proposing this change because collecting
information on emissions from aircraft that support OCS operations in
all plans would be unduly burdensome since aircraft emissions are a
small fraction of emissions in most plans and their inclusion would
likely not cause a facility's projected emissions to exceed the EETs or
any AAQSB in a State where it would otherwise not do so. Available data
from plans submitted to BOEM and its predecessors indicate that the
level of relevant emissions from aircraft is generally an extremely
small percentage of the total emissions reported in each plan.
Furthermore, there are a large number of aircraft supporting OCS
facilities and these aircraft service more facilities and are used for
a wider variety of purposes than MSCs, including for purposes other
than

[[Page 19738]]

supporting oil and gas facilities on the OCS. This makes it cumbersome
to accurately quantify and attribute (with respect to OCS support
functions) their emissions to individual facilities in a plan in many
cases. Accordingly, BOEM believes it is not prudent to require all
lessees and operators to report aircraft emissions.
The proposed rule, however, would require a lessee or operator to
submit aircraft emissions information to account for the situation in
which a plan proposes exceptional or unusual aircraft operations. This
provision would cover situations in which a lessee or operator plans
abnormally high use of aircraft to support its operations, or the
lessee or operator plans to use aircraft that emit exceptionally high
amounts of pollutants. In those situations, the proposed rule would
require the lessee or operator to determine whether aircraft emissions
would cause its projected emissions to exceed an emission exemption
threshold or AAQSB. If a plan which is already required to conduct
modeling results in incremental increases in concentration of a
pollutant that are greater than 95 percent of the value of a SIL, the
proposed rule would require the lessee or operator to also model its
aircraft emissions.\46\
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\46\ BOEM expects that aircraft emissions typically represent
less than two percent of all plan emissions, and that any plan with
emissions below 95 percent of the value of every SIL, excluding
aircraft emissions, would be extremely unlikely to generate total
emissions, even if including those from aircraft, in excess of any
SIL; therefore, modeling of aircraft emissions would normally not be
required.
---------------------------------------------------------------------------

Likewise, under the proposed rule, lessees and operators would not
normally be required to report information on emissions from onshore
support facilities. Emissions from large sources onshore are in many
cases already identified and regulated by the USEPA, or by the States
in the context of their respective SIPs.\47\ In addition, under the CAA
the USEPA has established standards for several types of mobile
sources, no matter where they are operated through requirements that
engines, vehicles, and equipment be certified to exhaust emission
limits, and through the regulation of certain characteristics of the
fuels used in these engines. The proposed rule would not require a
lessee or operator to gather or report the emissions generated onshore
in support of an OCSLA-authorized activity on the OCS. BOEM has
determined in the past and continues to hold that, for purposes of this
separate program, such emissions are de minimis and that further
regulation of them, beyond what already applies or that may be
established by USEPA and States under applicable federal and State law,
is not warranted. As would be the case with aircraft, however, if a
plan describes the use of onshore sources that generate unusually high
levels of emissions, such that these emissions could cause the
project's total projected emissions to exceed an EET or AAQSB, then the
lessee or operator would be required to provide information on its
onshore emissions.
---------------------------------------------------------------------------

\47\ USEPA regulates these sources to the extent they are in
source categories subject to New Source Performance Standards (NSPS)
or National Emissions Standards for Hazardous Air Pollutants
(NESHAP) coverage. States regulate them to the extent they are
covered in their State NSPS plans, have taken delegation of NESHAPs,
or have chosen to regulate them in order to meet criterial pollutant
NAAQS or under NSR.
---------------------------------------------------------------------------

While this proposal takes the approach described here for aircraft
and onshore emissions, BOEM is considering whether it should instead
establish a requirement whereby plans that propose aircraft and onshore
emissions above a certain threshold, expressed as either a percent of
the total plan emissions or an absolute amount of emissions, would have
to include emissions from aircraft and onshore support facilities. BOEM
would welcome comments on this approach, and also any data or analysis
relevant to the issue of whether, and to what extent, aircraft and
onshore emissions should be considered in evaluating a facility's
emissions profile.
Please provide comments on this approach and what threshold might
be most appropriate.

C. Points of Measurement

1. Point-of-Origin Measurement
Historically, BOEM applied ``point source'' modeling to plans for
facilities and their MSCs. Point source modeling evaluates all
emissions associated with any source as if they originated from a
single location, regardless of whether that source is stationary (e.g.,
a drilling unit or platform) or non-stationary (e.g., a supply vessel).
The term ``point source'' refers to the location from which the
pollutants are discharged, not the location at which the impacts from
the emissions are measured or evaluated (referred to as receptor
locations). In the case of a stationary facility, point source modeling
is appropriate because it accurately reflects where the emissions are
occurring.
With respect to non-stationary sources, however, point source
modeling is much less accurate because the actual emissions generated
by such a source are discharged over a broad area. BOEM's regulations
currently do not address the appropriate types of models to use to
account for emissions from non-stationary sources, although some
operators already model non-stationary emissions sources as (1) area or
line sources; (2) volume sources; or (3) so-called pseudo-points (i.e.,
some mobile sources are modeled as if their emissions originated at one
or more stationary points).\48\
---------------------------------------------------------------------------

\48\ In line-, area-, and volume-source models, the emissions
are modeled as if they are emitted evenly and continuously across a
line, area, or volume. In point source models, some emissions may be
modeled as if they are emitted from many discrete points along a
path or over an area.
---------------------------------------------------------------------------

MSCs operating in support of facilities on the OCS typically
discharge emissions continuously between the port and the facility.
BOEM believes line and volume source modeling for non-stationary
sources would accurately project the impact of emissions from such MSC
on onshore air pollution levels at the SSB. The improved accuracy and
information value from line and/or volume source modeling of pollutant
dispersions would provide BOEM a more realistic projection of actual
impacts on the air quality of a State.
With volume source modeling, it is also possible to more accurately
model the effect of emissions discharged by non-stationary sources on
fixed landscapes (i.e., land, mountains, lakes, etc.), taking into
account relevant factors, such as air pressure, currents, winds, and
temperatures in relation to the discharge of pollutants and their
ambient distribution at distant locations. With improved ambient air
quality dispersion data, air quality impacts can be evaluated more
effectively. BOEM requests comments on the various types of modeling
that could or should be used to more accurately reflect the origin and
dispersion of emissions that are generated by mobile sources, such as
MSCs, and under what circumstance volume source modeling would be
appropriate or inappropriate.
2. State Seaward Boundary (SSB)
In developing this proposed air quality rule, BOEM revisited an
issue it encountered while drafting its 1980 air quality regulations:
Whether air quality impacts should be evaluated starting at the
shoreline or at the SSB, which is typically three nautical miles
offshore, but which may be as much as nine nautical miles offshore
depending on the particular State. On the basis of BOEM's
interpretation of its statutory authority, BOEM has concluded that it
is more appropriate to measure at the SSB than at the shoreline.

[[Page 19739]]

Section 5(a)(8) of OCSLA requires DOI to regulate ``for compliance
with the national ambient air quality standards pursuant to the CAA (42
U.S.C. 7401 et seq.), to the extent that activities authorized under
[OCSLA] significantly affect the air quality of any State'' (43 U.S.C.
1334(a)(8)). BOEM historically interpreted the phrase ``significantly
affect the air quality of any State'' to limit it to considering those
effects that would occur landward of the shoreline. BOEM thus
historically has evaluated any OCS activity in terms of the effects of
that activity on the concentration of pollutants landward of the
shoreline.
BOEM has re-evaluated this position. BOEM believes the term
``State'' in section 5(a)(8) of OCSLA should be interpreted to include
the entire area of a State's jurisdiction extending to its seaward
boundary (either three or nine nautical miles seaward of its
shoreline). (See 43 U.S.C. 1312.) Moreover, the States are responsible
for attainment of the NAAQS over the entirety of the State including
their submerged lands. The USEPA interprets the CAA consistently with
BOEM's interpretation under this proposed rule. Generally, the USEPA
requires States to regulate their air quality up to their seaward
boundary. For instance, the USEPA does not allow States to permit an
onshore or offshore source that would cause the air quality above State
submerged lands to exceed an applicable AAI. In addition, the secondary
NAAQS are specifically intended to protect public welfare. Impacts to
the air quality above State submerged lands have the potential to
adversely affect a range of natural resources, such as marine mammals,
coral, fish, etc. that are included in the category of resources
protected under the secondary NAAQS. For these reasons, BOEM believes
that its regulations should ensure that OCS facilities not cause or
contribute to a violation of the NAAQS in any area of a State up to the
State's seaward boundary.
The USEPA has advised BOEM that a variety of environmental and
scientific studies have shown that changes in air quality have also
caused impacts to human health off the coast in near-shore areas. For
example, these include specific health impact studies for the NAAQS, as
well as port air quality analyses that show the impacts of emissions
from ships and diesel engines, diesel emissions studies (health effects
and ports)),\49\ information regarding environmental justice
populations in coastal areas,\50\ impacts to subsistence fishing on
fishing piers that extend into the near-shore areas,\51\ and the
sensitivity of native Alaskan populations.\52\ There also are studies
that trace the emissions from offshore and onshore sources to near-
shore and onshore areas. Although the available data are not yet
conclusive, BOEM proposes to consider and evaluate the impacts of air
pollution over State submerged lands,\53\ including Alaska.\54\
---------------------------------------------------------------------------

\49\ ``USEPA, Regulatory Impact Analysis: Control of Emissions
of Air Pollution from Category 3 Marine Diesel Engines, EPA-420-R-
09-019, December 2009.'' Available at: https://www.epa.gov/otaq/regs/nonroad/marine/ci/420r09019.pdf.
\50\ See Shell permits for:
(1) Kulluk: https://www.epa.gov/region10/pdf/permits/ocs/shell/kulluk/SoB_Draft_072211_Public_Comment.pdf, and https://www.epa.gov/
region10/pdf/permits/shell/kulluk/
SoB_Environmental_Justice_Analysis_Kulluk_072211_Public_Comment_07-
19-2011.pd\.
(2) Discoverer: https://www.epa.gov/region10/pdf/permits/shell/discoverer_supplemental_statement_of_basis_chukchi_and_beaufort_air_permits_070111.pdf and https://yosemite.epa.gov/oa/eab_web_docket.nsf/
Filings%20By%20Appeal%20Number/4BB1D10E49B2C0F585257934006FEFB8/
$File/Final%20Attachment%204...11.pdf.
\51\ Wolfe, R.J. 2004. Local traditions and subsistence: A
synopsis of twenty-five years of research in Alaska. Technical Paper
No. 284. Alaska Department of Fish and Game, Division of
Subsistence, Juneau, Alaska.
\52\ See Wernham, Inupiat Health and Proposed Alaskan Oil
Development: Results of the First Integrated Health Impact
Assessment/Environmental Impact Statement for Proposed Oil
Development on Alaska's North Slope, 2007; and Alaska Native Health
Status Report 2009 https://www.anthc.org/chs/epicenter/upload/ANHSR.pdf.
\53\ Although there are likely no particular studies that deal
with air pollution impacts specifically on the area over State
submerged land, the Statement of Basis (SOB) for the Shell permits
discusses these concepts as part of the air quality impacts analysis
for these permits. These SOBs also have appendices that go into more
detail about the air quality impact analysis.
\54\ Specifically with respect to the Alaskan OCS, the USEPA
prepared the following document on the OCS air quality impacts:
``Technical support document review of Shell's supplemental ambient
air quality impact analysis for the Discoverer OCS permit
applications in the Beaufort and Chukchi seas,'' United States
Environmental Protection Agency, Region 10, Seattle, Washington,
June 24, 2011.
See also, https://www.epa.gov/region10/pdf/permits/ocs/shell/kulluk/SoB_AppA_AQIA_072211_Public_Comment.pdf.
See also, https://www.epa.gov/region10/pdf/permits/ocs/shell/kulluk/SoB_AppA_AQIA_072211_Public_Comment.pdf. In addition, similar
analyses have been done by the USEPA's Region 4 in connection with
the issuance of OCS permits there. The SOB's in Region 4 are known
more generally as preliminary determinations and all can be found
at: https://www.epa.gov/region4/air/permits/ocspermits/ocspermits.html.
---------------------------------------------------------------------------

Though the proposed rule would impose stricter requirements than
exist under the current BOEM regulations, BOEM's requirements would
still differ from those of the USEPA. In accordance with section 328 of
the CAA, the USEPA requires, in areas where it has jurisdiction, that
any facility located on the OCS within 25 miles of the State seaward
boundary is subject to all the requirements of 40 CFR part 55. These
include, but are not limited to, the federal requirements as set forth
in 40 CFR part 55.13 (e.g., NSPS, NESHAPs and permitting requirements)
and the federal, State and local requirements of the corresponding
onshore area, and the area that is geographically closest to the source
or another onshore area that the USEPA Administrator designates (40 CFR
55.14).
BOEM welcomes comments and analysis on the potential impacts of
emissions generated from OCS sources on the air quality over State
submerged lands and/or the potential impact of such emissions on the
environment above such lands, as well as any scientific, technical, or
other information that can be provided to measure or evaluate the
impact of OCS-originated air pollutants on the area over State
submerged lands.
3. Point-of-Impact Measurement
Although current BOEM regulations provide that measurements of any
potential impacts of OCS emissions take place along the shoreline, they
do not specify from which point along the shore the emissions should be
evaluated when modeling is required. Because of this, it has generally
been assumed the ambient concentrations should be evaluated at the
point on the shoreline closest to the facility. This interpretation of
the proper approach is reinforced by the formula used for the exemption
threshold analysis, which requires operators to calculate the closest
distance between the facility and the shoreline. BOEM has published
instructions and a guidance document for BOEM forms BOEM-1038 (Gulf of
Mexico Air Emissions Calculations for EPs) and BOEM-1039 (Gulf of
Mexico Air Emissions Calculations for DOCDs), stating the measurement
point (for the purposes of calculating the distance parameter in the
emission exemption threshold formulas) should generally be the closest
point of land. See BOEM Web site, ``Reporting Instructions,'' available
at https://www.boem.gov/BOEM-0138-instructions/, and ``Tips to Avoid
Common Emissions Spreadsheet Errors,'' available at https://www.boem.gov/Form-0138-and-0139-Tips/. This approach works well in the
GOM, considering wind patterns and other relevant meteorological
conditions.
In evaluating meteorological data within the parts of the Chukchi
Sea OCS bordering Alaska, however, BOEM recognizes prevailing wind
patterns are often not from sea to shore (i.e., from north to south)
but rather move at an

[[Page 19740]]

angle, either from the northwest to southeast or from the northeast to
the southwest. Because of this, the point at which the air emissions
released from a facility would have the greatest effect (i.e., yield
the highest pollutant concentration) may be much farther along the
State's boundary than the closest point on that boundary. In order to
accurately model the potential effects of any given air pollutant on a
State, therefore, it is important that the effects of such air
emissions be evaluated not at the closest point of the State but rather
where the concentrations of emissions would be the highest (i.e., where
the potential impacts would be the greatest).
Because of this, the proposed regulations specify the effects of
emissions, for modeling purposes, would be evaluated at those locations
in the State(s) where the concentration of any given pollutant is
expected to be the highest. Additionally, the effects of emissions
would be evaluated in the non-attainment area where the concentration
of any given pollutant is expected to be the highest among non-
attainment areas for that pollutant (if different from the most
affected area). This location might be on land or over State submerged
lands. That location in the model would likely be the same for many,
but not necessarily all, pollutants. Those air pollutants, such as
O3, that are not directly emitted by a facility, but are
instead created in the atmosphere, are often more heavily affected by
climatological or meteorological conditions, which often cause them to
concentrate at a location different than other air pollutants. Given
technological advances, BOEM does not anticipate that adding additional
hypothetical receptor locations to the modeling should present any
technical difficulty but welcomes comments on how this requirement
could be implemented most effectively.
4. Ambient Air Quality Monitoring
Monitoring is a general term for on-going collection and use of
measurement data or other information for assessing performance against
a standard or status with respect to a specific requirement. In
general, there are two basic types of monitoring:

Ambient air quality monitoring, which collects and uses
measurement data (or other information) from onshore monitoring
stations or remote sensing); and
Emissions source monitoring, which involves collecting
and using measurement data (or other information) at individual
stationary sources of emissions (i.e., facilities, RUEs, pipeline
ROWs, etc.) to verify actual emissions of such sources, and validate
the effectiveness of ERM.

Thus, ambient air quality monitoring is the systematic, long-term
assessment of pollutant levels by measuring the quantity and types of
certain pollutants in the surrounding, outdoor air, whereas emissions
source monitoring is the process of monitoring particulate and gaseous
emissions from a specific source.
Air quality monitoring is carried out to assess the extent of
pollution, ensure compliance with national legislation, evaluate
control options, and provide data for air quality modeling. There are a
number of different methods to measure any given pollutant, varying in
complexity, reliability, and detail of data. These range from simple
passive sampling techniques to highly sophisticated remote sensing
devices. In general, monitoring strategies should carefully examine the
options to determine which methodology is most appropriate, taking into
account the initial investment costs, operating costs, reliability of
systems, and ease of operation.
Air quality monitoring stations are the most typical means for
obtaining ambient air quality information. The locations for monitoring
stations may depend on the purpose of the monitoring. Most monitoring
networks are designed with human health objectives in mind, and
monitoring stations are therefore established in population centers.
Many governments (local, regional or national) give specific guidelines
on where to monitor within these areas--next to busy roads, in city
center locations, or at a location of particular concern (e.g., a
school, hospital). Background monitoring stations are also established,
to act as a ``control'' when determining source apportionment.
Once data are collected from a monitoring system, they are then
stored in data management systems and databases. Subsequently, the data
must be retrieved and analyzed to see what they reveal about the
effectiveness of regulatory standards, the accuracy of modeling,
impacts on health endpoints, and as an overall way of assessing
potential impacts. In the U.S. these ambient air quality monitoring
data are collected and housed in the Air Quality System (AQS). The AQS
contains ambient air pollution data collected by the USEPA, State,
local, and tribal air pollution control agencies from thousands of
monitoring stations. AQS also contains meteorological data, descriptive
information about each monitoring station (including its geographic
location and its operator), and data quality assurance/quality control
information.
BOEM has relied on the USEPA's AQS data to determine the relevant
ambient air quality on which lessees and operators perform their
analysis of the AAI's and the NAAQS in connection with their submission
of plans and to comply with BOEM's air quality requirements in areas
under BOEM's air quality jurisdiction. BOEM has proposed that it should
evaluate the air quality of States to the State seaward boundary. There
are, however, few monitoring stations in relevant locations on the
coast and no monitoring stations in the ocean along the SSB. To improve
the accuracy of the estimates of the background concentrations of the
relevant pollutants, BOEM is investigating various alternatives for
collecting, utilizing and disseminating this information, including
technologies such as remote sensing and spectral analysis, and is
proposing flexibility to adopt such approaches in the future. The
proposed rule would allow BOEM the flexibility to consider adopting
such approaches that meet the proposed standard for effectiveness.
Otherwise, the relevant background concentrations would be obtained
from the relevant USEPA regional office, as is the case today.

D. Emission Exemption Thresholds (EETs)

Consistent with the current rule, the proposed rule would define
EETs as the maximum allowable rate of projected emissions, calculated
for each air pollutant, above which facilities would be subject to the
requirement to perform modeling. Functionally, these EETs would
establish those levels of projected emissions below which BOEM has
determined they would not cause or contribute to a violation of the
NAAQS or the AAIs. Under the proposed rule, if the USEPA revises a
NAAQS, or any applicable SIL or AAI, BOEM would examine the
appropriateness of its EETs,\55\ and, BOEM, at its discretion, would
periodically revise its exemption formula(s) or its exemption threshold
amount(s) for the corresponding air pollutant(s). Because USEPA has
recently revised many NAAQS, the proposed rule would allow revision of

[[Page 19741]]

the exemption formula(s) to reflect these revisions, without waiting
for further revisions to trigger a review under this update scheme.
---------------------------------------------------------------------------

\55\ The purpose of the EETs is to establish thresholds below
which BOEM believes there is no reasonable possibility that BOEM's
approval of a plan would cause a violation of any AAQSB in any
State. The EETs are intended to avoid forcing lessees and operators
to perform unnecessary air quality modeling in situations where no
benefit from such modeling could reasonably be anticipated.
---------------------------------------------------------------------------

The current EETs would continue in place under the proposed rule
until the relevant air quality studies have been completed and new
EETs, if necessary, are developed and implemented. At a future point in
time, but no later than 2020, BOEM will propose new exemption
thresholds for the GOM and Alaska OCS Regions by publishing a FR
notice. Subsequently after reviewing comments on the notice, BOEM could
finalize new exemption thresholds with another FR notice.
Consistent with the current rule, the proposed rule provides that,
if the projected emissions associated with a proposed facility are
exempt, then the lessee or operator would not be required to perform
air quality modeling described in proposed Sec. 550.304, or to apply
any emission reduction measure(s) (ERM), as described in proposed
Sec. Sec. 550.305 through 550.307.
New EETs are not being proposed in this proposed rule because the
scientific basis for determining the potential impacts on the States of
OCS emissions have not yet been established. The proposed rule,
however, would set a new policy governing how BOEM establishes emission
exemption thresholds in the future. Specifically, the proposed rule
would provide that BOEM would, sometime after the rule becomes
effective, publish new proposed EETs in the FR and provide the
opportunity for public comment. In the proposed rule, BOEM has included
a range of EETs within which BOEM may establish updated EETs for each
pollutant.
As long as the new thresholds fall within the exemption threshold
ranges proposed in this rule, BOEM would not implement them through a
separate rulemaking, though the new thresholds would not become final
until after BOEM received public comment. If, however, the proposed
thresholds were to fall outside these ranges, BOEM would implement them
through a separate rulemaking. A range would be established for each
criteria or precursor pollutant. The proposed rule would establish both
maximum and minimum emissions formulas for each pollutant, above and
below which, respectively, BOEM would not set new emissions thresholds
without conducting a new rulemaking process. As a result of the new
environmental exemption studies, which have previously been described,
a new set of formulas will be developed to update the EET formulas
currently in place. On an ongoing basis thereafter, BOEM would update
the EETs to reflect changes in the NAAQS, SILs, and AAIs; advances in
measurement and modeling technology; changes in pre-existing pollution
levels in the potentially affected States; and various other factors.
The current exemption threshold formulas take the distance of the
facility from the State into account because dispersion modeling would
indicate the impacts are likely to be lower as the distance involved
becomes greater. The proposed formulas for these minimums represent
emissions levels below which the ambient air impact at the nearest
point in a State would not exceed any SIL, taking distances into
account. However, there may be a more appropriate manner in which to
establish the minimums. For that reason, BOEM requests comments on the
EET formulas and the underlying analysis used in this rulemaking or
whether absolute values may be more appropriate. Until such time as
BOEM has determined new EETs and has published them in the FR (``the
date of the Notice''), the distance component of the emissions
exemption calculation would continue to be the distance of the facility
from shore. After the date of the Notice, each distance formula would
instead utilize the distance of the facility from the SSB.
After the date of the Notice, the lessee or operator would be
required to apply the new set of formulas for the EETs in effect at
that time (i.e., to determine whether projected emissions would be
exempt from further analysis). BOEM would use the following criteria to
determine the EET formulas: The absolute level of projected emissions;
the distance of the proposed facility or facilities from any State or
from critical natural resources, animals, fish and habitats; the
relative need to protect public health and welfare and the existing
amounts of air pollution in potentially affected States; the types,
frequency and duration of any air pollutant emissions and their
formation and/or dispersion characteristics; prevailing meteorological
characteristics; any USEPA AAQSB applied in this proposed rule; other
facilities and vessels located in the vicinity of the proposed
facility; and other necessary and appropriate considerations. Until
BOEM has established new formulas based on these criteria, the proposed
rule would provide that projected emissions are exempt if they are
below the current exemption formulas.
The intent of those provisions that would allow BOEM to modify the
EETs is to ensure that the exemption thresholds accurately reflect the
amounts of potential emissions that could adversely affect a State.
Because the NAAQS are subject to change as scientific knowledge
improves and because modeling techniques and methods may improve over
time, the emission exemption threshold formulas should also be subject
to change. Under the proposed rule, BOEM would revise the EETs on an
ongoing basis either as a result of a change in an applicable standard
or because BOEM's ability to measure and evaluate the impact of
existing EETs has improved.

E. Emissions Reductions Measures (ERM)

1. Emissions Credits and Offsets
Current regulations specify that BACT should be implemented as the
first and primary emissions control mechanism any time that a proposed
facility is estimated to exceeded a SIL. This BACT requirement was
meant to ensure consistency with the USEPA regulations as they existed
when the regulations were issued in 1980.
BOEM's rationale regarding this point has evolved to allow for
greater flexibility, while still protecting the air quality of
neighboring States. Under the proposed rule, if the projected emissions
associated with a proposed OCS facility exceed an AAQSB, operational
controls would be the first option to be considered. Operational
controls, such as limiting the hours of operation or operating at a
higher level of engine efficiency could be both more cost effective and
more successful in reducing incremental emissions, particularly in
those situations where the proposed exceedances are small. As an
alternative, lessees and operators would have the option of replacing
old or inefficient equipment with newer and less polluting equipment.
This could involve, for example, replacing a diesel engine with a
natural gas powered engine. If these options were not sufficient, other
ERM, including BACT and emissions credits, would then be
considered.\56\
---------------------------------------------------------------------------

\56\ The BOEM provision allowing for equipment replacements is
contingent on the lessee or operator complying with all other
applicable federal regulations, as noted in the proposed regulation
in section 550.309(f).
---------------------------------------------------------------------------

One change in this regard relates to emissions credits. Under the
current rule, offsets can only be used once the relevant BACT has been
deemed inadequate. Even then, the current rule provides no guidelines
as to how offsets might apply in situations other than to offshore
facilities. Other forms of emissions credits, such as emissions
trading, acquiring of trading program

[[Page 19742]]

allowances and so forth, are not addressed by the current regulation.
Under the proposed rule, emissions credits, which would include
offsets, are defined as: ``Emissions reductions from an emissions
source(s) not associated with the plan that are intended to compensate
for the excessive emissions of criteria or precursor air pollutants,
regardless of whether these emissions credits are acquired from an
emissions source(s) located either offshore or onshore, including: (1)
Emissions offsets generated by the lessee or operator directly; or (2)
emissions offsets acquired from a third party; or (3) trading
allowances or other alternative emission reduction method(s) or
system(s) associated with a market-based trading mechanism, such as a
mitigation bank, or through other competitive markets where these
assets are exchanged.'' Essentially this means that emissions credits
consist of any form of emissions reduction, regardless of whether such
reductions consist of physical or operational controls on non-plan
facilities (i.e., facilities other than those covered by the proposed
plan), or whether they consist of the use of market-based mechanisms
that involve reductions achieved through third parties. Under the
proposed rule, emissions offsets could consist of BACT applied by a
lessee or operator to another one of its own, previously approved,
facilities on the OCS.
The proposed rule would therefore considerably increase the
mechanism by which emissions reduction could be achieved. Under the
proposed rule, in cases where operational controls would not be
sufficient to achieve the required emissions reductions lessees and
operators would be able to utilize emissions credits, as opposed to
applying BACT to a facility in the proposed plan. The proposed rule
would also provide that lessees or operators who submit plans that
include emissions credits demonstrate that the operator has notified
the relevant State and that emissions credits be verifiable.
The selection of emissions credits in lieu of BACT would often
result in both a net cost savings and a net environmental benefit. The
savings would result from the greater flexibility afforded lessees and
operators to make the reductions either on their facility, on another
facility (either on the OCS or in waters above State submerged lands),
on some unrelated stationary emissions source onshore, or through
acquiring the emissions credits from a third party. Because older,
higher polluting facilities whose emissions would be easiest to reduce
are most frequently located on or near the shoreline, in most cases the
use of emissions credits would involve a reduction in the emissions
from an onshore stationary source or from an older oil and gas facility
located offshore in waters above State submerged lands.
Under the current regulations, offsets are only permitted if they
would cause a reduction of emissions on the OCS with respect to the
facilities covered by the proposed plan. Under the proposed rule, any
reduction in emissions that is accomplished within the same USEPA air
quality control region (AQCR) \57\ would be an acceptable emissions
credit. Thus, if a facility associated with a proposed plan were
required to reduce its emissions by 100 tons of NOX per
year, such a reduction could be generated from any other source within
the relevant AQCR, whether the source of that reduction is located on
the OCS, over State submerged lands, or onshore, and regardless of
whether the source of the reduction is stationary, such as a facility,
or mobile, such as an MSC.
---------------------------------------------------------------------------

\57\ An air quality control region (AQCR) is an area, designated
by the USEPA, that has common air pollution issues and which is
likely to be affected by the same sources of air pollutant
emissions. See 42 U.S.C. 7407. The term AQCR is defined at 40 CFR
51.100(m) and in 40 CFR 60.21(i). The current AQCRs are defined in
the USEPA regulations at 40 CFR part 81 subpart B.
---------------------------------------------------------------------------

As currently defined, the AQCR boundaries do not extend to include
the OCS and, for this reason, it may sometimes be difficult to
determine which AQCR would be most applicable. BOEM also recognizes
that some AQCRs are very large, so it may not be certain that offsets
in one part of the AQCR have a benefit to the area affected by offshore
emissions. BOEM requests comments on how to best to define the relevant
AQCR(s) and on whether there may be more appropriate alternative to
defining the offset-generating areas or how to best refine the approach
of applying AQCRs in this context.
The use of emissions credits in lieu of BACT would provide a net
environmental benefit because the use of emissions credits would
typically involve a reduction in emissions onshore or over State
submerged lands, at that point where the impact to State air quality is
greatest, rather than on the OCS, which might be far away from the
point at which any impact might be felt. For example, if an OCS
facility located 30 miles offshore were to be required to reduce its
emissions of NOX by 200 tpy, under the current regulations
that reduction would have to be achieved primarily by reducing the
emissions from the facility itself. As a result, the 200 TPY reduction
in NOX emissions from an OCS source might avoid the same
amount of ambient NOX at the shoreline that would be avoided
by only 20 TPY reduction in emissions at the shoreline. Given the
greater flexibility provided by the proposed rule, if a lessee or
operator instead decided to instead pay an onshore power plant to
reduce its emissions by the same 200 TPY of NOX, the net
impact to the State would be a reduction in onshore emissions of 200
TPY. Thus, the same reduction in NOX emissions could have a
much greater positive environmental impact. For more details on the
offset requirements, see the section-by-section analysis for section
550.309(e).
Furthermore, because the proposed rule does not prohibit the joint
acquisition of emissions credits, the proposed rule would allow
emissions credits to be obtained and divided among multiple lessees or
operators (presumably located near to one another in the vicinity of a
State) in order to potentially spread the costs of complying with air
quality requirements.
2. Applicability of Best Available Control Technology (BACT) Upon an
Exceedance of the Significant Impact Levels (SILs)
BOEM's current regulations require that any proposed plan that
identifies projected emissions of air pollutants that would result in
an exceedance of the SILs onshore is required to implement BACT (30 CFR
550.303(g) and 303(h)). Under existing BOEM regulations, ``Best
available control technology'' or BACT means an emission limitation
based on the maximum degree of reduction for each air pollutant subject
to regulation, taking into account energy, environmental and economic
impacts, and other costs. The BACT is required to be verified on a
case-by-case basis by the Regional Supervisor and may include
reductions achieved through the application of processes, systems, and
techniques for the control of each air pollutant.
Under the proposed rule, the evaluation of the SILs would not
automatically trigger the requirement for BACT. In fact, BACT would
never be the only possible ERM. Under the proposed rule, emissions
credits including offsets would always be available as an alternative.
The proposed rule would generally limit the requirement to apply BACT
and/or offsets (or, more generally, emissions credits) to situations
where the SILs exceedance relates to a non-attainment area. For a long-
term facility whose emissions affect only attainment areas, BACT and/or
offsets would be

[[Page 19743]]

required only if a further analysis indicates that the SIL exceedance,
taken in combination with all other facilities located in the same
general vicinity, would potentially cause an increase in the
concentrations of a relevant air pollutant that would endanger the
attainment status of some area in any State by exceeding the AAIs. In
all other cases, when the AAIs are not exceeded, the proposed rule
would not generally require further ERM.
For long-term facilities whose emissions affect a non-attainment
area, where an exceedance of the relevant SILs would trigger the
requirement for more extensive controls, BOEM expects that lessees and
operators would likely choose emissions credits in all but a few cases
(likely limited to those rare situations where localized control
equipment would be the only effective way to prevent the facility from
adversely affecting the attainment status of an onshore area).
3. ERM Evaluation Criteria
If the modeling results show impacts that are higher than the SILs,
ERM would be required as specified in Sec. 550.306, for a short-term
facility, or as specified in Sec. 550.307, for a long-term facility.
Current BOEM regulations require that any operator subject to controls
(because its emissions are projected to exceed the SILs as defined in
BOEM's regulations) must conduct a BACT analysis, and that BOEM must
evaluate the amount of emissions reductions that each available
emissions-reducing technology or technique would achieve, as well as
the energy, environmental, economic and other costs associated with
each technology or technique. The current regulations do not, however,
specify explicitly that each lessee or operator evaluate all the
potentially effective forms of BACT and do not therefore require a
consideration of all the feasible alternatives. This section describes
the methodology in this proposed rule for determining what forms of ERM
would be required for any given plan.
Under the proposed rule, a lessee or operator would be required to
identify all of the potentially feasible forms of ERM and rank them
according to their potential effectiveness. Only those situations where
a potentially more effective ERM is infeasible \58\ would such an
operator be allowed to propose less potentially effective forms of ERM.
---------------------------------------------------------------------------

\58\ In the case of BACT, the cost effectiveness of every option
must be considered and any alternative that is not cost effective
(in terms of the emissions reductions achieved) may be excluded as
non-viable.
---------------------------------------------------------------------------

The proposed rule would provide a two-stage procedure for analyzing
and selecting ERM, when required, based on modeling results. First, the
lessee or operator would identify all the alternative control
technologies available and determine their technical feasibility.
Second, the lessee or operator would rank and choose specific control
technologies. Although these two stages are implicit in BOEM's current
regulations, they are stated explicitly for the first time in this
proposed rule.
The purpose of this approach would be to ensure that the types of
ERM considered would be those that would have the greatest potential to
reduce the amount of emissions. The first stage in the process would
require lessees and operators to consider all technically feasible
control technologies (and not submit a plan that fails to mention
feasible options). No lessee or operator could propose only control
technologies that would either be largely ineffective (but inexpensive
to implement) or cost prohibitive (so they could be discarded) to avoid
selecting a cost effective and technologically effective form of ERM.
The second stage would require operators to demonstrate the selected
ERM is the most effective control technology that could be implemented
cost effectively. Under the proposed rule, the most effective
technology would always be considered, so it would be implemented
unless it was found not to be cost effective.
The effectiveness of any given form of ERM would be measured in
terms of the total number of tons of a pollutant that would be reduced
on an annual basis. The cost effectiveness would be the annual tonnage
reduction estimate divided by the cost. Thus, cost effectiveness would
represent the cost per ton of pollutant emissions averted through the
application of ERM. Both the amount of emissions reduced and the cost
effectiveness of any proposed or potential ERM can be evaluated for any
given pollutant or based on the total reduction in all relevant
pollutants, depending on which pollutants need to be reduced.
Determining cost effectiveness would require considering the
benefits to be achieved from emissions reductions against the costs
that would be incurred to achieve those benefits. Accordingly, cost
effectiveness means the absolute effectiveness of the technology (in
terms of tons of emissions avoided), and its emission control
efficiency (ECE) (percentage reduction) compared to the total potential
cost of the technology. All of the costs and benefits of any potential
control would be considered in determining what constitutes a cost
effective emission reduction measure and what would, therefore,
constitute viable ERM.
Although not stated explicitly, the current regulations allow a
lessee or operator to apply no controls whatsoever when its
``proposed'' BACT is claimed to be unfeasible. The proposed rule would
make explicit that technically feasible controls would always be
required but would allow much greater flexibility in how the relevant
ERM are determined and evaluated. Once the required emission reduction
measure(s) (ERM) are identified, a lessee or operator would be required
to thoroughly describe the emissions reduction controls it proposes to
apply. The rule would also provide specific provisions governing the
sufficiency and effectiveness of these measures and require a lessee or
operator to monitor its continual effectiveness over the duration of
the plan under reasonably foreseeable circumstances.
The proposed rule would also explicitly articulate requirements for
ERM that are implicit in the current regulations. The proposed rule
would retain the term BACT, though the definition would be rewritten
for clarity. In maintaining a ``performance-based'' approach to the
proposed rule, BOEM is not proposing specific types of BACT, technical
standards, or ERM. BOEM is seeking comment on whether it should
identify various forms of ERM that have been approved in other
situations, whether by BOEM, the USEPA or another regulator, and
whether BOEM should provide additional specificity on how to determine
the most appropriate form of ERM and/or what cost effectiveness would
be considered presumptively reasonable in making such a determination.
All of these issues could be addressed in the context of establishing
criteria for what may constitute ``presumptive BACT'' or presumptive
ERM. BOEM invites comment on whether BOEM should adopt presumptive ERM
and, if so, what processes it should use for adopting and updating the
various forms of presumptive ERM that are suggested or approved.
Section III of USEPA publication entitled ``PSD \59\ and Title V
Permitting Guidance for Greenhouse Gases,'' [Office of Air Quality
Planning and Standards, Air Quality Policy Division, Research Triangle
Park, NC, EPA-457/

[[Page 19744]]

B-11-001, March 2011] describes the USEPA's process for determining the
appropriate use of BACT.\60\ BOEM has examined the USEPA approach and
intends to take these guidelines into consideration in developing its
own guidelines for ERM, as well as for making a determination as to the
viability and cost-effectiveness of alternative forms of ERM ``taking
into account energy, environmental, and economic impacts and other
costs.'' Because BOEM intends to publish its own ERM guidelines, it
solicits comments on the USEPA's approach and the underlying
methodology for making the determination as to what forms of ERM may be
most appropriate under various circumstances, as well as comments on
why or under what circumstances the USEPA approach may or may not be
appropriate to the OCS environment and how the ERM requirements could
be best tailored to the unique conditions of the offshore oil and gas
industry.
---------------------------------------------------------------------------

\59\ PSD stands for Prevention of Significant Deterioration.
\60\ BOEM and the USEPA differ in their requirements for BACT,
primarily due to the difference in their respective regulatory
frameworks. BOEM reviews the BACT alternatives as part of its AQRP,
under both the current regulation and the proposed rule
prospectively, determining in advance of the facility installation
what form of BACT is appropriate. The USEPA also evaluates BACT
prospectively, but the CAA also specifies, among other requirements,
that BACT cannot be less stringent than any applicable standard of
performance under the New Source Performance Standards (NSPS) (42
U.S.C. 7479(3)). Therefore, although BOEM looks to USEPA practices
when evaluating control technologies, due to the unique nature of
the OCS, BOEM also exercises independent judgment on what
constitutes BACT and how it should be applied.
---------------------------------------------------------------------------

4. Nitrogen Oxides (NOX) Waiver and Volatile Organic
Compounds (VOC) Waiver
There are situations where the increase in a given precursor
pollutant will not contribute to an increase in the ambient air
concentration of the CP for which it is a precursor. That situation is
particularly important in the case of NOX and VOCs, which
are both precursors for O3. The USEPA has recognized that,
under certain circumstances an increase in NOX or VOC may
have no effect on the formation of O3 in the tropospheric
atmosphere and may, in fact, actually cause a decrease in O3
formation. The degree to which a change in the emissions of
NOX or VOCs would contribute to O3 formation in
the atmosphere is referred to as the O3 efficiency. Because
there are situations where an increase in NOX or VOCs would
have no negative or even a positive effect, BOEM is proposing to exempt
a facility from reducing its emissions of these precursor air
pollutants in such situations. Generally, VOC emissions must be greater
than NOX emissions to trigger O3 formation. A
ratio of VOCs to NOX of 4:1 to 16:1 is within the range
where O3 forms.\61\
---------------------------------------------------------------------------

\61\ This topic is addressed in more detail in the book
``Introduction to Atmospheric Chemistry,'' by Daniel J. Jacob,
Princeton University Press, 1999, available at the following
location: https://acmg.seas.harvard.edu/people/faculty/djj/book/bookchap12.html.
---------------------------------------------------------------------------

The USEPA allows the issuance of a ``NOX Waiver'' for
areas where limiting NOX emissions does nothing to decrease
O3, and in some cases, can actually increase O3.
A ``VOCs Waiver'' could similarly be issued in the reverse case (i.e.,
where there is already too much VOC in the atmosphere to further
contribute to the production of O3). The proposed rule would
adopt a similar approach and limit the mandate to reduce NOX
and VOC emissions, for the purpose of limiting O3 formation,
to those situations where the limits would be effective. Because
atmospheric conditions change over time, the rule would also propose
that, in the event that a facility is waived from controlling
NOX as a precursor to O3, or from controlling
VOCs for controlling O3, BOEM could re-impose the
requirement to set up ERM at some future date, if BOEM determined that
the waiver was not having the intended effect.

F. Consolidation of Emissions From Multiple Facilities

The proposed rule would require a lessee or operator to combine
projected emissions from its multiple facilities under certain
circumstances in order to evaluate whether the close placement of
multiple facilities operating at the same time could jointly cause or
contribute to a violation of the NAAQS. This proposed requirement would
only apply to facilities that are wholly or partially owned, controlled
or operated by the same entity, and is designed to prevent a single
entity from segmenting its operations into multiple plans to avoid
exceeding EETs. Emissions from nearby facilities that are not wholly or
partially owned, controlled or operated by the same entity would be
reviewed in the context of the relevant NEPA analyses.
BOEM's current practice is to require, in specific circumstances,
the consolidated analysis of facilities covered by multiple plans in
accordance with the following provision of Sec. 550.303(j): ``If,
during the review of a new, modified, or revised Exploration Plan or
Development and Production Plan, the Regional Supervisor determines or
an affected State submits information to the Regional Supervisor which
demonstrates, in the judgment of the Regional Supervisor, that
projected emissions from an otherwise exempt facility will, either
individually or in combination with other facilities in the area,
significantly affect the air quality of an onshore area, then the
Regional Supervisor shall require the lessee to submit additional
information to determine whether emission control measures are
necessary.'' The current regulations do not specify under what
circumstances the Regional Supervisor would make such a determination.
This proposed rule recognizes the fact that the emissions from two
or more OCS facilities located in close proximity to one another may
have an adverse impact on the air quality of a State even if the
individual EETs, considered separately, would indicate that that
facility should not cause an adverse impact to the air quality of a
State. This would generally only be true in the situation where two or
more facilities were operated contemporaneously, however. Closely-
grouped facilities that emit pollutants at the same time can affect the
air quality of a State differently than facilities that are spread
across a larger area because the emissions would be more concentrated
and would, correspondingly, cause a greater concentration of air
pollution within a neighboring State. Accordingly, the proposed rule
would require consolidation to prevent a lessee or operator from
``segmenting'' his operations by describing proximate activities in
separate plans or RUE or pipeline ROW applications in order avoid
modeling or applying controls.
The proposed rule would specify that a lessee or operator would be
required to consolidate projected emissions from multiple facilities
if: (1) The emissions from multiple facilities are generated by
proximate activities (i.e., the same well(s); a common oil, gas, or
sulphur reservoir; the same or adjacent lease block(s); or, by
facilities located within one nautical mile of one another); (2) the
lessee or operator wholly or partially owns, controls or operates those
facilities; (3) the construction, installation, drilling, operation, or
decommissioning of any of the lessee or operator's facilities occurs
within the same 12-month period as the construction, installation,
operation, or decommissioning of another facility that meets conditions
1 and 2; and, (4) such a consolidation of emissions from multiple
facilities would generate emissions sufficient to exceed an applicable
emission exemption threshold. If two or more facilities meet all of
these conditions, under the proposed rule, the lessee or operator

[[Page 19745]]

would be required to calculate the sum of the projected emissions from
those facilities (including its respective attributed emissions).
The proposed rule would specify that, if all of the emissions to be
combined relate to the lessee's or operator's wholly-owned facilities,
the lessee or operator would be required to provide the data and
analysis regarding the complex total emissions. However, where the
lessee or operator only partially owns the facilities whose projected
emissions are to be consolidated, the lessee or operator would need to
gather data from the operator of any facility that it does not wholly
own \62\ or which it does not operate and would need to provide to BOEM
all the data and analysis it gathered. BOEM would make a determination
that the lessee or operator has appropriately considered the relevant
data in its analysis of the complex total emissions.
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\62\ All BOEM plan approvals and data are publically available
and can be obtained from the BOEM Web site.
---------------------------------------------------------------------------

Under the proposed rule, if any lessee or operator is required to
consolidate projected emissions data from multiple facilities, then
anywhere a requirement applies to projected emissions, the lessee or
operator would instead be required to use complex total emissions
(except with respect to the process by which projected emissions are
determined for any given facility, as specified in Sec. 550.205(d)).

G. Ongoing Monitoring and Review of Projected Emissions

BOEM is proposing mandatory record keeping of fuel usage and
activity data for all emissions sources, and we are proposing that non-
exempt facilities subject to emissions reductions controls or
mitigation and facilities that are exceptionally large be required to
monitor their actual emissions. BOEM expects that most of the
monitoring that would be required to be implemented in connection with
the proposed rule would be of the type known as a Predictive Emissions
Monitoring System (PEMS).\63\
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\63\ For an overview of PEMS as well a general background
discussion of other monitoring systems that may also be appropriate
in certain contexts on the OCS, see citation to this Web site:
https://cfpub.epa.gov/oarweb/mkb/Basic_Information.cfm.
---------------------------------------------------------------------------

PEMS is an air quality monitoring that provides continuous data
recording and generates reports according to the applicable regulatory
requirements. PEMS is used to meet 40 CFR part 60, appendix B,
requirements for audit and performance standards on new stationary
sources. It is also applied in many other contexts, including the PSD
program (40 CFR 51.166 through 51.166), and the approval and
promulgation of implementation plans (under 40 CFR 52.21). The USEPA
generally regards PEMS as a secure and reliable means of collecting,
storing, and reporting compliance data.
PEMS can be used on most combustion sources that fire gaseous or
liquid fuels and for most compliance parameters such as NOX,
SO2, CO, CO2, O2, hydrocarbons,
NH3, hydrogen sulfide, and formaldehyde. BOEM welcomes
comments on the potential application of PEMS and/or the best
approaches for selecting and evaluating monitoring systems.
1. Recordkeeping and Measurement Criteria
In order to ensure ongoing compliance with the NAAQS, the proposed
regulations would authorize BOEM to collect additional information on
activities or plans after they have been approved.
Under the current structure, BOEM approves all plans for facilities
in advance of the construction and installation of such facilities on
the OCS. With respect to air quality, the plans contain estimates of
prospective pollutant emissions based on the information that is
available about the most likely emissions for every emissions source
that is proposed to be used. This process necessarily involves
estimates because it utilizes emissions projections for equipment, much
of which is not yet in use at the particular site. The same principle
applies to proposed ERM. The ERM that are put into the plan are also
prospective; the ERM would not be applied to the facilities, equipment
or MSCs until after a plan has been approved. The effectiveness of any
physical controls that have not yet been installed cannot be measured
but only projected. Based on this approach, it would be difficult to
determine what the actual emissions would be for one facility, on a
stand-alone basis, let alone a range of support vessels, vehicles,
aircraft and ancillary equipment. For this reason, namely, in order to
provide greater confidence that the actual emissions levels are not
exceeding the projected levels, BOEM has proposed a more reasonable
approach to establish basic record-keeping and measurement criteria
that could be applied after a plan has been implemented and the
associated facilities are fully operational.
The proposed rule adds a requirement that all operators (1) keep
fuel logs for all the relevant equipment and (2) maintain operating
records (e.g., operating times by level of capacity) for all key
facilities, MSCs, and equipment described in the proposed plan. The
information would need to be maintained on a month-by-month basis and
would need to be provided to BOEM according a schedule determined by
the respective BOEM region.
In addition to requiring all facilities to keep records as
described above, certain facilities would also be required to measure
actual emissions at specified intervals. The proposed rule outlines
four criteria that would be used to determine which facilities would be
subject to this requirement. First, the proposed rule would require the
measurement of air pollutant emissions for plans which are approved
subject to BACT. Such plans would have to demonstrate their actual
emissions were not significantly above the projected emissions. Second,
the proposed rule would require that any facility or emissions source
that is not certified or compliant with USEPA emissions requirements
applicable to engines or equipment intended or certified for use in the
U.S. should also be required to demonstrate that its levels of actual
emissions nevertheless are consistent with the estimates provided in
the plan. Because the equipment is not certified, it is impossible to
know without actual measurement the extent to which emissions are
similar to emissions from certified equipment. Accordingly, BOEM
believes that a demonstration should be made that the actual emissions
of such equipment complies with the emissions levels which BOEM
approved as part of the plan review.
Third, there are some situations where the accuracy and reliability
of estimates of projected emissions, based on emissions factors, are
unreliable or would be subject to a great range of variation. BOEM
proposes to require measurement and reporting of actual emissions for
plans in which the projected emissions cannot be reliably determined or
in situations where the potential error in the emissions factors could
result in a significant underestimate of the projected emissions
(particularly in situations where the underestimate is of such a
magnitude that not addressing the error could have a significant impact
upon a State's air quality). This requirement is intended to allow BOEM
to require monitoring on facilities with high emissions or a high level
of variability in the accuracy of emissions factors or estimates.
Because projected emissions are based on an activity rate and an
emissions factor and because emissions factors are somewhat uncertain,
the difference between the projected

[[Page 19746]]

emissions and actual emissions will increase with higher activity
rates. So, the range of potential projected emissions for larger
facilities is much greater than those for smaller facilities, and the
potential ramifications for errors are larger than for small
facilities. Although this provision would likely be rarely invoked, it
is important that BOEM can verify the actual emissions of large
facilities in situations where it has evidence to believe that the
actual emissions are under-reported.
Finally, in some areas, particularly those where the background
concentrations of a pollutant are high or where the USEPA has recently
changed a standard, and where there is a greater likelihood of a nearby
facility causing or contributing to a violation of the NAAQS,
monitoring of actual emissions may also be required. The modeling that
was used to demonstrate that there is, presumptively, no such impact
could only be valid if the assumptions regarding the actual background
concentrations of pollutants are accurate. If a model of potential
emissions were to rely on inaccurate background concentration
estimates, its conclusions would also be suspect. For that reason, BOEM
has proposed that these facilities in these areas may also be required
to verify that their emissions correspond to those estimated in the
plan.

H. Structure of the Proposed Rule

In contrast with the current BOEM regulations, where air quality
data provisions are set forth in many sections, including Sec. Sec.
550.215, 550.218, 550.224, 550.225, 550.245, 550.249, 550.257, 550.258,
and 550.284, the proposed rule would establish one set of data
requirements related to air quality in a new Sec. 550.205. In the
current regulations, plan requirements applicable to EPs are dealt with
in one part of the regulations, and plan requirements applicable to
DPPs and DOCDs are dealt with in another part of the regulations.
Because the air quality requirements applicable to EPs, DPPs, and DOCDs
are largely the same, BOEM proposes to place all the plan requirements
relevant to air quality in one consolidated section.
The majority of the proposed rule consists of two major parts: A
new section on data requirements and collection, Sec. 550.205; and an
air quality analysis control and compliance subpart, 30 CFR part 550
subpart C. The content of the two primary air quality data sections
from the current regulations, Sec. 550.218 and 550.249, would be
covered by proposed Sec. 550.205, and those existing sections would be
eliminated.
The proposed rule would replace the current subpart C, which
includes air quality evaluation and analysis and requirements for the
application of emissions reductions measures. This new proposed subpart
would describe the process for post-approval review of plans and for
addressing compliance with future changes to the AAQSB on the part of
the USEPA. BOEM is proposing to change the title of subpart C from
``Pollution Prevention and Control'' to ``Air Quality Analysis,
Control, and Compliance,'' to better reflect the scope and intent of
this subpart.
To make the regulations more precise and to ensure they remain up-
to-date, BOEM is proposing to add a number of new definitions and to
clarify a number of existing definitions. The proposed rule would
consolidate all the definitions and acronyms specific to air quality in
a single section, replace or update various provisions, and clarify the
regulations in those circumstances where the existing text could be
considered unclear or potentially subject to more than one reasonable
interpretation.
1. Potential Monitoring Alternatives
BOEM solicits comments on various alternatives that could be used
to achieve the Bureau's objective of monitoring large emitters. The
following are examples of alternatives that have been identified. In
addition, there may also be other alternatives that should be
considered.
One alternative would be for BOEM to require measurement of actual
emissions on facilities with emissions above a specific threshold to be
determined in the final rule. BOEM would like comments on what an
appropriate threshold might be.
A second alternative would be for BOEM to establish general
criteria that could be used to determine the potential error in the
emissions estimates. Among the criteria being considered are:
Production volume of the facility, size, type, and efficiency of
engines proposed to be used, the age of equipment, the attainment or
designated non-attainment status of the nearby areas within any State,
the length of time the equipment will be operated, the proximity to
other facilities, and/or the historic reliability and variability of
emissions factors for the equipment being used. Under this alternative,
BOEM would make a determination on a case-by-case basis whether any
given facility would be required to report its actual emissions.
A third alternative would be to require actual emissions measures
for any plan that proposes to use equipment with emissions factors that
BOEM has determined to be particularly unreliable. Under this
alternative BOEM would provide information to lessees and operations as
to what specific types of equipment would be subject to this reporting
requirement.
The fourth alternative would be to establish a monitoring and
reporting formula whereby facilities whose projected emissions exceed a
fixed percentage of the emission exemptions thresholds would be
required to monitor and record their actual emissions. For example,
BOEM could require that any facility with projected emissions for any
CP that exceeds 85 percent of the threshold would have to report its
actual emissions for all criteria and major precursor pollutants. This
is due to the potential margin of error in the emissions factors. BOEM
solicits comments on the appropriate percentage of the emissions
exemptions thresholds for this reporting threshold. A fifth alternative
would be any combination of the previous alternatives.
BOEM is also considering whether it should require measurement of
actual emissions from activities in all plans, but limit the kinds of
sources for which measurement is required, based on the uncertainty in
the emissions factors estimates for specific pieces of equipment and
the potential costs of measuring emissions from the associated
equipment. The section-by-section description of proposed Sec. 550.311
sets forth text for this proposal.
In addition to monitoring requirements, BOEM is also proposing
provisions that clarify the way in which BOEM will ensure that
previously approved plans comply with the statutory requirements. As
noted previously, OCSLA requires ``compliance with the national ambient
air quality standards pursuant to the CAA (42 U.S.C. 7401 et seq.), to
the extent that activities authorized under [OCSLA] significantly
affect the air quality of any State'' (43 U.S.C. 1334(a)(8)). BOEM
believes this provision should properly be interpreted to mean that
BOEM has a continuing obligation to ensure the protection of State air
quality and that such obligation extends to ensuring compliance with
the NAAQS, as they are amended to incorporate new and more accurate
scientific information regarding the potential adverse public health
and welfare impacts of air pollution.

[[Page 19747]]

Because the NAAQS are updated periodically to reflect improved
information, BOEM believes that it would be appropriate to re-evaluate
plans or RUE applications approved many years ago for compliance with
section 5(a)(8) of OCSLA, even though the facility has not been
modified in such a manner as to require the submission of a revised
plan. For this reason, in addition to the new record-keeping and
emissions measurement requirements, BOEM is also proposing that lessees
and operators be subject to a requirement to resubmit their plans on a
periodic basis for re-evaluation. The current practice, and one that
would be continued under the proposed rule, is to project air emissions
for ten years from the date of plan submission. Under the proposed
rule, if a lessee or operator is operating under an approved plan, it
would be required to resubmit a plan for a periodic air quality review
ten years after BOEM's previous approval of the operator's last plan.
This provision would be added in furtherance of the objective of
section 5(a)(8) of OCSLA, which requires BOEM to ensure compliance with
the NAAQS, and which makes no provision for any exceptions with respect
to previously approved plans. All of the applicable requirements of
this subpart in effect on the date of resubmission would apply on the
same basis to a resubmitted plan as for an initial plan or RUE
application. BOEM requests comments on this provision, particularly
with respect to the potential impact on lessees and operators.
2. Plan Resubmittals
Once the new EETs have been established, BOEM would conduct
periodic reviews of plans that were approved prior to that time. This
is to ensure the lessee or operator's emissions remain compliant with
OCLSA and are in accordance with the provisions of the OCS leases that
require compliance with subsequent revisions to the regulations. Plans
would be resubmitted according to the schedule in proposed Sec.
550.310(c), no more frequently than ten years after they were approved.
Plans that were revised or modified would also be due for resubmittal
ten years after their most recent revision or modification was
approved.
A plan resubmitted pursuant to this proposed provision would be
required to be updated to comply with the requirements of Sec. 550.205
as they exist at the time of the plan resubmission and to include the
most current data on emissions factors. It would be reevaluated against
the EETs and formulas as they exist at the time of the plan
resubmission. The resubmitted plan must be modified to include any data
collected on actual emissions since the last time the plan was
submitted or resubmitted. Under the proposal, if a plan would indicate
an exceedance of any applicable emission exemption threshold, all of
the other applicable requirements of this subpart would apply as for an
initial plan.
For plans that were approved prior to the effective date of this
rule, the lessee or operator would be required to resubmit the air
quality component of its previously approved plan after the date in
which BOEM has determined new EETs and published them in the FR. The
resubmission would be conducted on a phased basis, beginning in 2020.
For further details, see the section-by-section analysis description of
proposed Sec. 550.310(c)(2).

I. Gulf-Wide Offshore Activities Data System (GOADS)

The proposed rule would include a new provision to support BOEM's
effort to inventory emissions on the OCS. Currently, BOEM maintains
this type of emissions inventory information on air pollutants in the
GOM Region. BOEM collects the information through GOADS, as described
most recently in BOEM NTL No. 2014-G01, and previous NTLs. The major
pollutants for which BOEM has collected data in the GOADS include the
following: CO, sulphur oxides (SOx), NOX, PM
(including both PM10, and PM2.5), and volatile
organic compounds (VOCs), including exempted compounds (40 CFR 51.100).
BOEM also has collected information on GHGs, including CO2,
methane (CH4), and N2O through the GOADS.
The proposed rule would codify this current GOM practice, provide
for the expansion of this activity to the North Slope Borough of the
State of Alaska, and facilitate the gathering of information in other
OCS areas to the extent necessary to augment the NEI or for another
purpose such as to obtain relevant NEPA data. The proposed provision
would require all lessees, operators, and holders of rights-of-use and
easements (RUEs) to collect, maintain, and submit information on an
ongoing basis regarding air pollutant emissions from all relevant
emissions sources. BOEM would use this information to maintain a
comprehensive OCS emissions inventory of air pollutants.
The information would assist BOEM in meeting its requirements under
OCSLA to ensure the offshore activities it authorizes do not
significantly affect the air quality of a State. Also, the information
submitted under this provision would allow BOEM to determine OCS-wide
emissions for leased areas and use that data to inform NEPA analysis
and coordinate with the USEPA and coastal States to determine ambient
air quality levels and mitigations of adverse impacts. The inventory
will continue to augment BOEM's NEPA review by providing an accurate
inventory to determine ambient concentrations of air pollutants and by
serving as a basis to compute emission trends and to perform necessary
air quality impact assessments. Separately, the data provided by
lessees, operators, and RUE holders are analyzed and supplemented by
BOEM, and the results are provided to the submitters in order to assist
them in complying with their reporting obligations to the USEPA. Under
the proposed rule, BOEM would continue to make this information
available to OCS lessees, lease operators, and RUE holders to assist
with their mandatory reporting of certain GHGs to the USEPA. See 40 CFR
98.233.
OCSLA requires DOI to make a decision on whether to approve an EP
within 30 days and a DPP within 60 days. Consequently, the air quality
review process for the plan is limited in its ability to provide
extensive analysis of complex plans. Although not mentioned explicitly
in OCSLA, BOEM's regulations require a similar review timeframe for
DOCDs. While there is an opportunity for public comment on plans, there
is limited opportunity for public review of air pollution measures in
EPs, DPPs, or DOCDs. BOEM requests comments on how more opportunity for
public input could be provided, while observing legal constraints on
plan review timeframes.

J. Prevention of Significant Deterioration

The AAIs established by the USEPA represent ambient concentrations
of CPs in attainment areas that have been established to prevent the
significant deterioration of air quality. Increases in ambient
concentrations of CPs that exceed the AAIs present a risk of causing an
attainment area to become a non-attainment area. BOEM proposes to
evaluate increases in ambient air concentrations to ensure compliance
with the AAIs.
The preamble to the current regulation \64\ stated that the maximum
allowable increases (when added to the baseline concentration) ``are
ceilings which cannot be exceeded within an applicable area. To
calculate the acceptable emission level, a lessee must

[[Page 19748]]

combine the ambient air concentrations resulting from the projected
emissions of total suspended particulates and SO2 from the
proposed OCS facility with those emissions of TSP and SO2
from other onshore and offshore sources which contribute to the
consumption of the maximum allowable increases.'' There is, however, no
provision in the current BOEM regulations that explicitly requires
accounting for ``other onshore and offshore sources which contribute to
the consumption of the maximum allowable increases.''
---------------------------------------------------------------------------

\64\ 45 Federal Register (FR) 15133 (Mar. 7, 1980).
---------------------------------------------------------------------------

Accordingly, the proposed rule would contain an explicit
requirement that facilities for which BACT is implemented consider
other sources of emissions that contribute to consumption of the AAI
when they compare the impacts of their controlled emissions against the
AAIs.
Through this notice, BOEM is soliciting comments on alternative
ways for how it might effectively ensure that the increments are not
``consumed'' in the relevant attainment areas or what steps it might
take to protect the increments in an operational context without
creating an undue burden on lessees or operators. One alternative for
determining the extent to which the increments have been ``consumed''
would be to separately evaluate the cumulative effects of offshore
development in the context of the NEPA analysis conducted for the Five-
Year Oil and Gas Leasing Program or in connection with the lease sales.
Another alternative might be to conduct periodic cumulative impact
assessments of the air quality in relevant attainment areas. Based on
either the NEPA analysis or a separate cumulative impact assessment,
BOEM might maintain a database of relevant AAIs that have previously
been ``consumed.'' These data could be evaluated in the context of the
plan review process, or separately in some other context.

V. Section-by-Section Analysis of the Proposed Rule

The following are the changes proposed by this rulemaking in part
550:

A. 30 CFR Part 550, Subpart A

Section 550.101--Applicability
The heading of Sec. 550.101 would be revised from ``Authority and
Applicability'' to read ``Applicability.'' This change would make the
section title better reflect the current content of the section.
Section 550.102--What does this part do?
The proposed rule would modify paragraph (a) of this section to
make clarifying amendments. In addition, paragraph (b), which contains
the table entitled ``Where To Find Information For Conducting
Operations,'' would be updated as follows with the following additions:
The acronym for application of permit to drill (APD); a reference to
the subsection on Development and Production Plans (DPP) to include
Development Operations Coordination Documents (DOCD); the acronym for
geological and geophysical (G&G) permits; the acronym from oil spill
financial responsibility, (OSFR); a subsection to cover Rights-of-Use
and Easement; acronyms for Rights-of-Use and Easement (RUE) and
pipeline Rights-of-Way (ROW); and a new subsection referencing the Air
Quality proposed regulations in subpart C.
Section 550.105--Revised Definitions
Note on Definitions
The definitions in Sec. 550.105 are intended to apply to all of
part 550. The definitions proposed to be added or revised in proposed
Sec. 550.302 are meant to apply only to Sec. 550.205 of subpart B and
all of subpart C.
In many cases, the definitions as used in part 550 differ from the
meaning of the same term found in other agencies' regulations, in other
contexts, or as used in common usage. Any word, phrase, or term that is
not defined should be understood in the common and ordinary meaning of
that word, phrase, or term. For example, the term nitrogen oxides is
not defined, and it is not used in a manner that would require the term
to be defined uniquely in this proposed rule, because BOEM uses it in
its common and ordinary meaning. In contrast, the phrase ``Best
Available Control Technology,'' and its corresponding acronym BACT, is
used as defined in proposed Sec. 550.302, and it would not have the
same meaning as used in the USEPA regulation.
Definitions related to air quality terms are currently located in
three places in part 550: Sec. Sec. 550.105, 550.200, and 550.302.
Under the proposed rule, definitions of terms that are related solely
to air quality would be located in Sec. 550.302 as part of subpart C.
Other definitions related to both air quality and other parts of the
regulations are left in Sec. 550.105. Subparts A and B contain some
requirements related to air quality, and proposed sections within these
subparts would use terms that would be defined in subpart C. Under this
organizational framework, the proposed rule would move some of the
definitions from one section to another and some terms would also be
updated.
The proposed rule would revise or add definitions of the following
terms:
Air Pollutant
This definition would be revised to include the following: (1) Any
criteria air pollutant for which the USEPA has established numerical
criteria, referred to as the primary or secondary National Ambient Air
Quality Standards (NAAQS), in 40 CFR part 50 and as may be amended
pursuant to section 109 of the CAA; (2) any major precursor air
pollutant identified by the USEPA that contributes to the formation of
a criteria air pollutant through an atmospheric or photochemical
reaction, including, but not limited to, VOCs, NH3, and
those CPs that are also precursors for other CPs (such as
SO2); and (3) any USEPA-defined GHG, as defined at 40 CFR
98.6 and as may be amended pursuant to section 111 of the CAA; and, (4)
any USEPA-defined Hazardous Air Pollutant, as defined at 40 CFR 63.2
and as may be amended pursuant to section 112 of the CAA. The purpose
of this change is to clarify that, while there are many types of air
pollutants, the focus of BOEM's regulatory efforts in this rulemaking
is on the criteria and major precursor pollutants.
Emissions Source
The current regulations define the term ``source'' in section
550.302 as, ``an emission point. Several sources may be included within
a single facility.'' The proposed rule would replace the term
``source'' with ``emissions source'' and locate the newly defined term
in section 550.105. The proposed rule would define ``emissions source''
as ``a device or substance that emits air pollutant(s) in connection
with any authorized activity described in your plan.'' The proposed
definition would also clarify that several emissions sources may exist
on a single facility, aircraft, vessel, or vehicle. The proposed rule
would further make clear anything that: (1) Produces or results in the
release of one or more air pollutant(s), including the flashing,
flaring, or venting of natural gas; (2) involves burning any oil or
well test fluids; or (3) generates fugitive emissions, is an emissions
source.
BOEM is proposing to use the term ``emissions source'' in place of
the current term, ``source,'' since the term is used only in the air
quality context (although referred to throughout part 550 of the
regulations). The proposed definition of ``emissions source'' would be
broader than the existing definition of ``source.'' It would also
clarify that an

[[Page 19749]]

emissions source need not be part of a single facility. Examples of
equipment that would fall under this proposed definition include, but
not be limited to: Boilers/heaters/burners, diesel engines, drilling
rigs, combustion flares, cold vents, glycol dehydrators, natural gas
engines, natural gas turbines, pneumatic pumps, pressure/level
controllers, amine units, tanks, dual fuel turbines, sources involved
in mud degassing, storage tanks, well testing equipment, vessels
(including support vessels, pipeline lay barges, pipeline bury barges,
derrick barges), and any other equipment that could cause fugitive
emissions, venting, losses from flashing, or loading losses.
Federal Land Manager (FLM)
The proposed rule would add this term to mean the Secretary of the
Department with authority over any federal Class I area or sensitive
Class II area (or the Secretary's designee). This definition is adapted
from USEPA regulations at 40 CFR part 51, subpart P, implementing the
CAA provisions on protecting visibility in Class I areas.
Federally-Recognized Indian Tribe
For the purpose of this proposed rule, a Federally-recognized
Indian tribe refers to a Federally-recognized Indian tribe that has
either a Treatment as State (TAS) status recognized by the USEPA or an
approved Tribal Implementation Plan (TIP).
Flaring
Under the current Sec. 550.105, ``flaring'' is defined as ``the
burning of natural gas as it is released into the atmosphere.'' The
proposed rule would revise this definition to read, ``. . . the burning
of natural gas or other hydrocarbons and the release of the associated
emissions into the atmosphere.'' The proposed definition would also
provide that, because lessees and operators can use flaring to reduce
the emissions of hydrocarbon vapors, it could potentially also be
considered as an air pollutant emission reduction measure. The proposed
definition would further make clear flares can be a mechanism used to
control emissions from storage tanks, loading operations, glycol
dehydration units, vent collection systems, and amine units. In
addition, the proposed definition would note flares usually operate
continuously but some are used only for process upsets, which occur
during the exploration or development process when large amounts of
flammable gases are released suddenly and unexpectedly. Finally, the
proposed definition would provide the term ``flaring'' is equivalent to
combustion flaring (i.e., burning of the gases), but it is distinct
from cold venting, which involves the discharge of raw pollutants into
the air without burning.
BOEM is proposing to revise the definition of flaring and
distinguish it from venting as a result of a response to Report 11-34
by the Government Accountability Office (GAO) in ``FEDERAL OIL AND GAS
LEASES: Opportunities Exist to Capture Vented and Flared Natural Gas,
Which Would Increase Royalty Payments and Reduce Greenhouse Gases.''
Minerals
The proposed rule would revise the definition of the term
``minerals'' slightly to align with OCSLA section 2(q), 43 U.S.C.
1331(q). There would be no substantive changes to the definition for
minerals, which continues to include oil, gas, sulphur, geopressured-
geothermal and associated resources, and all other minerals that are
authorized to be produced from public lands.
Mobile Support Craft (MSC)
The proposed rule would add this term to the definitions section to
mean ``any offshore supply vessel (OSV) as defined by the USCG in
accordance with 46 U.S.C. 2101, and any ship, tanker, tug or tow boat,
pipeline barge, anchor handling vessel, facility installation vessel,
refueling or ice management vessel, oil-spill response vessel, or any
other offshore vessel, remotely operated vehicle (ROV), or any offshore
vehicle used by, or in the support of, the offshore operations
described in a plan.''
Consistent with the approach currently used by BOEM, for the
purpose of evaluating air emissions, an MSC is considered a facility
while temporarily attached to the seabed or connected to another
facility.
Offshore Supply Vessel
The term ``offshore supply vessel'' is defined in the USCG
regulations. The term ``support vessel'' is used but not defined in the
current BOEM regulations.\65\ BOEM's regulations do specify, however,
that the meaning of the term support vessel includes crew boats, supply
boats, anchor handling vessels, tug boats, barges, ice management
vessels, and other vessels, some of which do not qualify as offshore
supply vessels under the USCG definition. Because of the potential
confusion that could be caused by utilizing a term similar to that used
by the USCG, BOEM proposes to revise its existing regulations and
replace the term ``support vessel'' with a new term, ``Mobile support
craft,'' which would include offshore supply vessels as defined by the
USCG, as well as any other vessel or vehicle used to support OCS
exploration, development, production or transportation operations.
---------------------------------------------------------------------------

\65\ See 30 CFR 550.224 and 550.257.
---------------------------------------------------------------------------

Offshore Vehicle
Current Sec. 550.200 defines ``offshore vehicle'' as ``a vehicle
that is capable of being driven on ice.'' The proposed definition would
clarify that an offshore vehicle is a type of MSC that is capable of
being driven on ice and would add the phrase ``and which provides
support services or personnel to your facility or facilities.''
Right-of-Use and Easement (RUE)
RUE is not currently defined in 30 CFR part 550. The proposed rule
would define RUE to mean seabed use authorizations that BOEM may grant
at an OCS site, other than an OCS lease, pursuant to sections
Sec. Sec. 550.160 through 550.166 of this part.
State
State is not currently defined in the regulations. The proposed
rule would add this definition in order to clarify that the word
``State'' includes its submerged lands and extends to the federal/State
boundary. Any reference to the word ``State'' in this proposed rule,
unless otherwise specified, is intended to include the area offshore a
State up to the federal/State boundary.
Venting
Venting is currently defined in 30 CFR 250.105. The proposed rule
would modify that definition to read ``the release of gas into the
atmosphere, including though a stack without igniting it, whereby
relief flows of natural gas or other hydrocarbons are directed to an
unignited flare or which is otherwise discharged directly to the
atmosphere. This includes gas that is released underwater and bubbles
to the atmosphere.''
Section 550.141--May I use or be required to use alternate
documentation, procedures or equipment?
The proposed rule changes the title from ``May I ever use alternate
procedures or equipment?'' and would add new paragraph (d) to existing
Sec. 550.141, stating, ``In order to protect public health, you may be
required or allowed to temporarily suspend the use of equipment that
emits air pollutants, or to implement operational control(s) on the use
of such equipment by the Regional Supervisor, when an adjacent

[[Page 19750]]

State or locality declares an air quality episode or emergency,
provided that any such suspension or operational control(s) would not
cause an immediate threat to safety or the environment.'' The purpose
of this provision is to ensure any BOEM-authorized equipment, which
might contribute to air emissions episodes or air quality emergencies,
could be turned off, or operated in a limited capacity, for the
duration of such a declared emergency, as long as it can be done
safely.
Local air quality authorities in States adjacent to the OCS
periodically declare air emissions episodes or air quality emergencies
when the concentration of a pollutant is especially high. BSEE and its
predecessors have historically either required or allowed the
suspension of use and testing of standby equipment during emergency
health episodes declared by local authorities adjacent to the Pacific
OCS (NTL 2000 P-01). Such suspensions have, for example, allowed
Pacific OCS operators the ability to curtail stationary source
emissions according to the measures contained in Episode Avoidance
Plans or Emergency Action Plans, which the operators typically prepare
at the request of either the USEPA or the State. The proposed provision
would apply more generally to any equipment authorized under part 550
and that emits air pollutants. It would also apply anywhere on the OCS
where operations could contribute to an air quality emergency.
A new provision has been added to accommodate situations in which
published documents that are referred to in the regulations of this
part have been updated by the original publisher. This provision would
allow the use of the updated publications under certain circumstances,
as specified in the proposed rule text.
Section 550.160--When will BOEM grant me a right-of-use and easement,
and what requirements must I meet?
The proposed rule would redesignate current paragraphs (f), (g),
(h), and (i) as paragraphs (g), (h), (i), and (j) and add a new
paragraph (f). The new paragraph would specify that facilities
constructed or maintained on RUEs must meet the air quality
requirements of Sec. 550.205 of subpart B of this part and that
subpart C would also apply to that RUE application. The rule clarifies
that any reference to a lessee or operator in those sections would
apply equally to any applicant for a right-of-use and easement.
The new provision of this section is intended to apply to those
situations where an organization is proposing to install a new facility
on a RUE and that facility is not included in an exploration or
development plan. In the event that an existing RUE was approved as
part of an exploration or production plan, no new requirements would be
imposed. Similarly, any application for a new RUE that is included
within the scope of a proposed exploration or development plan would
not be affected by the requirements of this paragraph.
BOEM requests comments on the most appropriate method for
establishing and reporting air quality requirements associated with the
removal of any facility installed pursuant to a RUE in the context of
the AQRP.
Section 550.187--What region-wide offshore air emissions data must I
provide?
The proposed rule would add new Sec. 550.187. The new section
would require a lessee, an operator, or a holder of a RUE to collect,
maintain, retain for a period of no less than 10 years, and submit to
the appropriate regional office on an ongoing basis according to a
schedule established by BOEM, information regarding all air pollutant
emissions from all emissions sources associated with its operations.
The primary means by which this requirement would be implemented is by
requiring the lessees and operators to maintain records of the type and
amount of fuel consumed (i.e., fuel logs) by all relevant sources. BOEM
would use this information to maintain a comprehensive OCS emissions
inventory of air pollutants. Currently, BOEM maintains this type of
emissions inventory information on air pollutants in the GOM Region
with the GOADS. The proposed rule would replace the name ``GOADS'' with
the name ``OCS emissions inventory'' because the proposed rule
anticipates the data collection would not be limited to the GOM in the
future.
The current BOEM practice is to require the submission of this
information every three years, and BOEM intends to maintain this
practice for the foreseeable future. The three-year timeframe is
consistent with USEPA regulations regarding the timeframes for
submitting this information. However, given that the USEPA may change
its regulations and given that, in some cases, current USEPA
regulations require more frequent reporting from some sources, the
proposed regulations cross-reference USEPA regulations with respect to
the timing of the information submittal. That way, the rule would
propose to automatically reflect any changes made by the USEPA with
respect to the NEI timing requirements. Accordingly, the proposed rule
would specify that the reporting timeframes will be determined by the
requirements of 40 CFR 51.30(a), as it may be amended.
The proposed rule would require that the submitted information
include air emissions or the activity data necessary to calculate the
emissions of stationary emissions sources, including all facilities,
and all non-stationary sources, including MSC(s) and any other non-
stationary emissions source(s) of air pollutants above the OCS or above
State submerged lands that operate in support of an OCS facility, as
determined by the Regional Supervisor. GOM has historically obtained
the MSC data from independent sources and intends to continue this
process for the foreseeable future. BOEM would likely only change this
practice if the data collection became impractical.
Under the proposed rule, a lessee or operator may request that the
owner of such non-stationary emissions source(s) provide the
information to BOEM or a BOEM-designated agent, but the lessee or
operator would still be responsible for submitting the required
information if the owner does not submit it.
Currently, the GOM Region prepares its emissions inventory by
allowing lessees and operators to directly input data either on fuel
use or on equipment usage and operating time. BOEM then uses this data
to calculate the resulting emissions. This proposed rule would allow
for the continuation of that practice in the GOM Region, and the
expansion of that practice to other OCS regions. Accordingly, the
proposed rule requires the submission of (1) facility and equipment
usage, including hours of operation at each percent of capacity for
each emissions source; and/or (2) fuel logs containing monthly and
annual fuel consumption data showing the quantity, type, and sulphur
content of fuel used for each emissions source. The proposed rule would
require the information provided under this proposed section should be
at a sufficient level of detail so as to facilitate BOEM's compilation
of a comprehensive OCS emissions inventory of air pollutants. BOEM
solicits comments on various alternative methods for ensuring the
accurate reporting of emissions and the appropriate methods that might
be used to ensure the accuracy of the data and information it collects.
Consistent with the approach taken by the USEPA in the development
of the NEI, the proposed rule specifies that lessees and operators
would be required to classify the emissions according to

[[Page 19751]]

the appropriate SCCs as defined by the USEPA in their Source
Classification Codes listing, incorporated by reference in section
198(b)(1)(iv) of this chapter. The purpose of this requirement is to
distinguish the various emissions processes including mobile source
processes. The USEPA also estimates mobile source emissions of
commercial marine vessels and without this distinction there would be a
risk that either BOEM or the USEPA could double count the emissions
that are reported.
Finally, the proposed rule would allow the Regional Director to
waive or allow a delay in compliance with the requirements of this
section on a region-wide basis. The reason for this waiver provision is
to allow regions to avoid duplicating the effort already undertaken by
the USEPA in this regard, particularly in areas where BOEM does not
have air quality jurisdiction and does not, therefore, have any unique
or separate data or IC requirements.
Under the proposed rule, a lessee, an operator, or a holder of a
RUE would be required to submit the required information upon request
or on an ongoing basis as determined by BOEM starting in 2017 or in the
next reporting period if the rule is not effective by 2017 and
continuing according to the timeframe established by the USEPA in its
regulations governing the NEI to the appropriate regional OCS office.
Leases and RUEs acquired after 2017 would be subject to the reporting
requirement at the end of the next reporting period. The proposed rule
would also require submission of this information more frequently if
the lessee, operator, or holder of a RUE has an emissions source that
generates facility emissions that have a PTE \66\ such that it would
qualify as a Type A source according to the USEPA's regulations in
table 1 of appendix A of subpart A.--Emission Thresholds by Pollutant
for Treatment as Point Source of 40 CFR 51.50. These regulations
contain thresholds set by the USEPA to determine which emissions
sources within States require annual reporting to States for the NEI
that the USEPA conducts for other sources every three years.
---------------------------------------------------------------------------

\66\ The USEPA concept of PTE, which it defines at 40 CFR
51.301, is similar to the BOEM concept of facility emissions, in
that both PTE and facility emissions refer to the maximum aggregate
capacity of a stationary source to emit a pollutant under its
physical and operational design. This concept includes all emissions
sources attached to a facility but excludes the attributed emissions
of non-stationary sources, such as MSCs. For further details on the
concept and use of PTE in the USEPA context, see ``Potential to
Emit: A Guide for Small Business,'' USEPA, Office of Air Quality
Planning and Standards, Research Triangle Park, NC, EPA-456/B-98-
003, October 1998, available at: https://www3.epa.gov/airtoxics/1998sbapptebroc.pdf.
---------------------------------------------------------------------------

As with the current GOADS in the GOM OCS region, the information
obtained under this proposed provision is necessary to allow BOEM to
determine more accurately air emissions from the activities it has
authorized on the OCS and fulfill its statutory obligations under OCSLA
section 5(a)(8). BOEM also uses that data to inform NEPA reviews and
analysis and coordinate with the USEPA and coastal States. The
inventory would provide data to augment BOEM's NEPA review by providing
an accurate basis from which to compute emission trends and to perform
necessary air quality impact assessments. In addition, the emissions
data derived from information provided under this program would
continue to be made available from BOEM to OCS lessees, operators, and
RUE holders to assist with their mandatory reporting of GHGs to the
USEPA. BOEM would also continue to use the inventory to meet
information requests from the general public.
BOEM currently collects emissions data related to GHGs on a regular
basis in the GOM OCS Region as part of the GOADS program. BOEM
recognizes the impacts of GHG emissions on the air and water overlying
the OCS, primarily associated with ocean acidification, and the States,
in connection with climate change, and the importance and sensitivity
of this issue. For this reason, BOEM is researching the implications of
GHG emissions generated by OCS facilities and MSCs and evaluating
various alternatives for potentially limiting these GHG emissions.
Section 550.198--Documents Incorporated by Reference
The proposed rule would incorporate by reference certain material
into part 550 with the approval of the Director of the Federal Register
under 5 U.S.C. 552(a) and 1 CFR part 51. The proposed rule would
provide for the process BOEM may use to amend its regulations to
incorporate different versions of these documents.
For all material incorporated by reference, the applicable document
would be the specific edition or specific edition and supplement or
addendum cited in this section. Lessees and operators would be allowed
to comply with a later edition of a specific document incorporated by
reference, provided they show that complying with the later edition
provides a degree of scientific or technical accuracy, environmental
protection, or performance equal to or better than would be achieved by
compliance with the listed edition; and they obtain the prior written
approval for alternative compliance from the authorized BOEM official.
The proposed rule would explain that the effect of incorporation by
reference of a document into the regulations in this part is that the
incorporated document is a requirement. The proposed rule states that
when a section in this part incorporates all of a document, the lessee
or operator would be responsible for complying with the provisions of
that entire document, except to the extent that the section which
incorporates the document by reference provides otherwise. Further it
states that when a section in this part incorporates part of a
document, the lessee or operator would be responsible for complying
with that part of the document as specified in that section.
BOEM may issue the a future rule(s) amending the documents
incorporated by reference effective without opportunity for public
comment when BOEM determines the revisions to a document represent new
industry standard technology and do not impose undue costs on the
affected parties; and BOEM meets the requirements for making a rule
immediately effective under 5 U.S.C. 553.
The specific documents proposed to be incorporated by reference
include: From the U.S. Environmental Protection Agency's Office of Air
and Radiation, 1200 Pennsylvania Ave. NW., MS6101A, Washington, DC
20460.
(1) AP 42, Fifth Edition, Compilation of Air Pollutant Emission
Factors, Volume 1: Stationary Point and Area Sources, January 1995,
incorporated by reference at proposed Sec. 550.205(b)(2). AP-42,
Compilation of Air Pollutant Emission Factors, has been published since
1972 as the primary compilation of the USEPA's emission factor
information. It contains emission factors and process information for
more than 200 air pollution source categories. A source category is a
specific industry sector or group of similar emitting sources. The
emission factors have been developed and compiled from source test
data, material balance studies, and engineering estimates. The Fifth
Edition of AP-42 was published in January 1995. Since then the USEPA
has published supplements and updates to the fifteen chapters available
in Volume I, Stationary Point and Area Sources. The latest emissions
factors are available on their Web site at: https://www3.epa.gov/ttnchie1/ap42/.
(2) Motor Vehicle Emission Simulator (MOVES), User Guide,
Assessment and Standards Division, Office of Transportation and Air
Quality, EPA-

[[Page 19752]]

420-B-14-055, July 2014, incorporated by reference at proposed Sec.
550.205(b)(2)(iii)(B). The USEPA's Motor Vehicle Emission Simulator
(MOVES) is a state-of-the-science emission modeling system that
estimates emissions for mobile sources at the national, county, and
project level for criteria air pollutants, greenhouse gases, and air
toxics. MOVES2014 is the latest version of MOVES. It incorporates
significant improvements in calculating onroad and nonroad equipment
emissions. MOVES201a does not significantly change the criteria
pollutant emissions results of MOVES2014 and therefore is not
considered a new model for SIP and transportation conformity purposes.
The User Guide is available from the USEPA at: https://www3.epa.gov/otaq/models/moves/documents/420b12001b.pdf.
(3) User's Guide for the Final NONROAD2005, EPA420-R-05-013,
December 2005. This publication is applicable to the NONROAD2008 model,
incorporated by reference at proposed Sec. 550.205(b)(2)(iii)(B). The
NONROAD model is intended for estimation of air pollution inventories
by professional mobile source modelers, such as state air quality
officials and consultants. The User Guide is available from the USEPA
at: https://www3.epa.gov/otaq/models/nonrdmdl/nonrdmdl2005/420r05013.pdf.
(4) FIRE (Factor Information Retrieval System) Version 5.0: Source
Classification Codes and Emission Factor Listing for Criteria Air
Pollutants, Office of Air Quality Planning and Standards, Office of Air
and Radiation, EPA 454/R-95-012, Research Triangle Park, NC 27711,
August 1995, incorporated by reference at Sec. 550.187(c)(4). This
document provides emissions factors and Source Classification Codes
(SCCs) from the USEPA's Factor Information Retrieval (FIRE) system,
version 5.0, for use in the estimation, storage and retrieval of point
source air pollutant emissions. Calculation of emission estimates is
discussed as well as the SCC system of associating air pollution
estimates with identifiable emitting process types or unit
applications. This document is available from the USEPA at: https://www3.epa.gov/ttn/chief/old/efdocs/454r95012.pdf.
From the Federal Aviation Administration (FAA), Office of
Environment and Energy (AEE-100), 800 Independence Avenue SW.,
Washington, DC 20591:
(1) Aviation Environmental Design Tool (AEDT) User's Guide, Version
2B, prepared for the FAA Office of Environment and Energy (AEE-100),
Washington, DC prepared by U.S. Department of Transportation and Volpe
National Transportation Systems Center, Cambridge, MA, July 2015 (as
amended) incorporated by reference at Sec. 550.205(b)(2)(iii)(D). AEDT
is a software system that models aircraft performance in space and time
to estimate fuel consumption, emissions, noise, and air quality
consequences. AEDT is a comprehensive tool that provides information to
FAA stakeholders on each of these specific environmental impacts. AEDT
facilitates environmental review activities, such as those required
under NEPA, by consolidating the modeling of these environmental
impacts in a single tool. AEDT is designed to model individual studies
ranging in scope from a single flight at an airport to scenarios at the
regional, national, and global levels. AEDT leverages geographic
information system (GIS) and relational database technology to achieve
this scalability and offers rich opportunities for exploring and
presenting results. Versions of AEDT are actively used by the U.S.
government for domestic aviation system planning as well as domestic
and international aviation environmental policy analysis. The User
Guide is available from the FAA at: https://aedt.faa.gov/Documents/UserGuide.pdf.
(2) Aviation Environmental Design Tool (AEDT), Version 2B, AEDT
Standard Input File (ASIF) Reference Guide, prepared for the FAA of
Environment and Energy (AEE-100), Washington, DC prepared by U.S.
Department of Transportation and Volpe National Transportation Systems
Center, Cambridge, MA, May 2015 (as amended) incorporated by reference
at Sec. 550.205(b)(2)(iii)(D). This Reference Guide provides a
description of the AEDT Standard Input File (ASIF) file format. It is
intended for analysts and programmers who wish to create or modify an
ASIF to import data into an AEDT study. The Reference Guide is
available from the FAA at: https://aedt.faa.gov/Documents/ASIFReferenceGuide.pdf.
From the International Maritime Organization, 4 Albert Embankment,
London SE1 7SR, United Kingdom, or https://www.imo.org, or 44-(0)20-
7735-7611:
(1) Revised MARPOL Annex VI, Regulations for the Prevention of Air
Pollution from Ships, and NOX Technical Code [NTC] 2008,
2009 edition, incorporated by reference at proposed section
550.205(b)(2)(v). This publication presents the revised MARPOL Annex
VI, Regulations for the prevention of air pollution from ships, and the
updated NOX Technical Code 2008, including amendments
adopted by resolutions MEPC.202(62), MEPC.203(62) and MEPC.217(63), as
well as Guidelines and other information relevant to improved energy
efficiency for ships and the prevention of air pollution. MARPOL Annex
VI includes requirements for control of emissions from ships (chapter
3) and new regulations on energy efficiency for ships (chapter 4) that
entered into force on 1 January 2013. These make mandatory the Energy
Efficiency Design Index (EEDI) for new ships and the Ship Energy
Efficiency Management Plan (SEEMP) for all ships. The publication is
available from the International Maritime Organization (IMO) at: https://www.imo.org/en/Publications/Documents/Newsletters%20and%20Mailers/Mailers/IB664E.pdf.
This, and the other IMO publications, may also be ordered directly
from the IMO at: https://www.imo.org/en/Publications/Documents/Catalogue%20and%20Book%20Code%20Lists/English/Catalogue.pdf.
(2) Revised MARPOL Annex VI, Regulations for the Prevention of
Pollution from Ships (``2008 Annex VI''), incorporated by reference at
proposed Sec. 550.205(b)(2)(v). This adds various amendments to the
annex of the protocol of 1997 to amend the International Convention for
the Prevention of Pollution from Ships. It is available from a USEPA
Web site at: https://www3.epa.gov/nonroad/marine/ci/mepc58-23-annexes13-14.pdf.
(3) NOX Technical Code 2008, incorporated by reference
at proposed Sec. 550.205(b)(2)(v). This document amends the technical
code on the control of emissions of nitrogen oxides from marine diesel
engines. It is available from the IMO Web site at: https://www.imo.org/en/OurWork/Environment/PollutionPrevention/AirPollution/Documents/Air%20pollution/Resolution%20MEPC.177(58)%20NOx%20Technical%20Code%202008.pdf.

B. 30 CFR Part 550, Subpart B

The following are the changes proposed by this rulemaking in part
550:
Section 550.200--Definitions
Offshore Vehicle
The proposed rule would move the definition of this term into Sec.
550.105 because it is used more often outside the air quality context
and is referred to throughout the regulations in part 550.

[[Page 19753]]

Section 550.205--What air emissions information must be submitted with
my plan (EP, DPP, DOCD, or application for a RUE, pipeline ROW, or
lease term pipeline)?
In the current regulations, plan requirements related to air
quality are widely dispersed. Air quality requirements are discussed
throughout part 550, particularly in Sec. Sec. 550.207, 550.212,
550.218, 550.224, 550.225, 550.227, 550.242, 550.249, 550.257, 550.258
and 550.261. In order to provide a consistent, comprehensive listing of
all of the data requirements related to air quality, these existing air
quality regulations would be consolidated in one new section, ``Sec.
550.205 What air emissions information must be submitted with my plan
(EP, DPP, DOCD, or an application for a RUE, pipeline ROW, or lease
term pipeline)?'' Most references to air quality requirements in the
other sections of part 550 would be deleted and replaced with a cross-
reference to the single new Sec. 550.205. In addition, the proposed
rule would specify that this section would apply to RUE, pipeline ROW,
and lease term pipeline applications.
Paragraph 550.205(a)--Emissions Sources
The proposed rule would make clear that all lessees or operators
must list and describe every emissions source on or associated with any
facility or facilities and MSC(s) described in a plan. In contrast to
the current regulations, the proposed rule describes in detail what
should be considered an emissions source and what should or should not
be included in that category. The proposed rule adds specificity to the
requirements to ensure plans and RUE, pipeline ROW, and lease term
pipeline applications are prepared consistently and evaluated according
to a standard set of criteria. This would include each emissions source
used during the construction, installation (including well protection
structure installation), and operation of any exploration, testing,
drilling (including well test flaring), development, or production
equipment or facility or facilities (including every platform or
manmade island included in their plan). The proposed rule would specify
lessees or operators must account for the air pollutant emissions
sources associated with all drilling operations, including workovers
and recompletions, sidetracking, and pipeline construction, and
reported emissions sources must include those associated with any oil
or gas produced on a lease that is used during the course of lease
operations (i.e., any beneficial use of produced oil or gas). The
proposed rule would require the list of emissions sources to cover the
duration of the proposed plan's activities.
The proposed rule would require lessees or operators to specify the
equipment type and number, manufacturer, make and model, location,
purpose (i.e., the intended function of the equipment and how it would
be used in connection with the proposed activities covered by the plan)
and physical characteristics of each emissions source. It would also
require reporting of the type and sulphur content of fuel stored and/or
used to power each emissions source and the frequency and duration of
the proposed use.
The proposed rule would contain additional provisions for engines
on facilities and MSCs. For all engines on each facility, including
non-road engines, marine propulsion engines (in the case of MODUs when
attached to the seabed), or marine auxiliary engines (i.e., a nonroad
or highway engine on a vessel that is used to power a crane, a drill,
or an auxiliary power unit, but it is not installed on a marine vessel,
as defined at 40 CFR 1042.901), the lessee or operator would be
required to identify and provide the engine manufacturer, engine type,
fuel type, engine identification, and maximum rated capacity of the
engine, to be expressed in kilowatts (kW), if available. If a lessee or
operator has not yet determined what specific engine would be used, it
would be allowed to provide analogous data for a comparable engine with
the greatest maximum rated capacity for the type of engine that it will
use. For this purpose, BOEM would consider a comparable engine to be
one having similar operational and emissions characteristics and
similar operational and physical limitations. Under the proposal, if
the engine for which the lessee or operator provides documentation has
physical design and operational limitations and these limitations are
the basis of its emissions calculations, then the lessee or operator
must provide documentation of such limitations.
For engines on MSCs, including marine propulsion and marine
auxiliary engines, the proposed rule would require lessees or operators
provide information regarding the engine displacement in liters/
cylinder, and maximum speed in revolutions per minute (rpm). If the
specific rpm information is not available, the proposed rule would
require the lessee or operator to indicate whether the rpm would be
less than 130 rpm, equal to or greater than 130 rpm but less than 2,000
rpm, or equal to or greater than 2,000 rpm, based on best available
information.
For offshore vehicles and MSCs, the proposed section would provide
that when a lessee or operator does not know which specific engines
will be used or the information about them cannot be verified, it may
estimate maximum potential emissions based on the maximum potential
emissions of the type of MSC typically used in the planned operations.
Finally, for any emissions source that does not fall into one of
these categories, the proposed rule would require lessees or operators
to provide all information needed to calculate and verify the
associated emissions, such as volumes vented, volumes flared, size of
tank, number of components, etc.
Paragraph 550.205(b)--Emissions Factors
The purpose of this section is to provide information regarding how
a lessee or operator would determine the level of air emissions for
each emissions source described in its plan. The proposed rule would
provide a considerable amount of detail regarding what emissions
factors should be used. Emissions factors are the values that allow
lessees or operators to calculate how much of a pollutant will be
emitted based on the operation of the source. The proposed rule would
retain the current requirement that, for each emissions source, for
every criteria and major precursor air pollutant, the lessee or
operator must identify the most appropriate emissions factor(s) for
calculating its projected emissions. The proposed rule would specify
the acceptable methods to be used for determining the appropriate
emissions factors. In general, a lessee or operator would be allowed to
use actual emissions amounts derived from emission testing done for a
specific emissions source in lieu of one of the approaches to estimate
emission factors set out below. When determining the emissions factors
through testing, the lessee or operator must consider test points and
fuel. In general, unless the unique circumstances of the proposed plan
make it clearly impractical to do so, test points should be devised
based on actual operations as opposed to using the test points and
engine loads contained in one of the various marine or non-road duty
cycles. It cannot be assumed that emissions per hour or emissions per
kW or per hp hour from large main engines on drill ships and platforms
are highest during full load or

[[Page 19754]]

near-full load operation. Large main engines on drill ships and
platforms typically operate at less than half full power, and emissions
factors for some pollutants during this operation may be significantly
higher than at full load or near-full load. Specifically, actual
maximum emissions per hour or emissions per kW or horse-power hour may
not be properly estimated by assuming 90% load, since emissions factors
for different pollutants can have different variation with load. Under
the proposed rule, the emissions factor and emission per hour or
emissions per kW or per horse-power hour for the operation that is
actually expected should be determined, and the emissions under 90%
load should be used only if emissions at this load are the highest and
thus conservative.
The proposed rule would further specify that the lessee or operator
must ensure that the fuel used in the testing to generate the emission
factors reflect the type of fuel that will be used by the engine in
actual operation. The sulphur content is especially important with
respect to measuring PM and SOX emissions.
The proposed rule would specify that in the event that the lessee
or operator were to elect not to measure the actual emissions for any
given emissions source, it would need to select an emissions factor
from the list of sources provided in the proposed rule. These are
described below, in the order of preference.
First, the proposed rule would provide that the lessee or operator
use the emissions factor(s) that are vendor-guaranteed or provided by
the manufacturer of the specific emissions source, if available. If the
lessee or operator were to use vendor-guaranteed or manufacturer data,
it would need to demonstrate (1) that the fuel used by the manufacturer
to generate the emission factors reflects the type of fuel that will be
used by the engine in actual operation and (2) that the actual engine
has not been modified outside the configuration used to generate the
emission factors; thus, the emission factors used in the plan must
represent the actual pattern of use for that equipment in operations.
The proposed rule would specify that where a manufacturer has not
provided an emissions factor for the emissions source the lessee or
operator proposes to use, the lessee or operator may use a
manufacturer's emissions factor for a similar source only if the lessee
or operator could demonstrate to the satisfaction of the Regional
Supervisor that the emissions generated by the lessee or operator's
emissions source are the same as or lower than that for which a
manufacturer's emissions factor is available.
Second, the proposed rule would state that emissions factors
generated from source tests required by USEPA Outer Continental Shelf
permits would be allowed as BOEM emission estimates for a specific rig
since these emissions factors are based on prior emissions tests. These
emissions tests are required across the range of actual load operations
for engines on Mobile Offshore Drilling Units (MODU). The proposed rule
would further specify that if emissions factors were not generated
through testing for a particular engine, emissions factors generated
from a recent and similar permitted engine may be used.\67\ Data from a
rig from the same manufacturer, having an engine of the same model and
year would generally be allowed, unless the Regional Supervisor has a
reason to believe that such data may not be accurate or reliable.
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\67\ I.e., the same make, model and year engine would be
required.
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Third, if emission factors, based on models or an emission model
guidance document developed by the USEPA or FAA is available and
appropriate to the emissions source, the lessee or operator may use the
relevant emission factors from that model or guidance document. The
proposed rule would provide a list of emission models that may be used
to obtain emission factors for certain types of emissions sources. In
particular, two referenced documents from the USEPA provide in-use
emission factors for a variety of engines including ``Category 3'' main
propulsion engines on vessels and engines used in equipment on vessels,
covering both engines certified to USEPA emission standards and engines
certified by other nations and international organizations.
Fourth, the lessee or operator would use emission factors from
published studies conducted by a reputable source, such as the South
Coast Air Quality Management District, California Air Resources Board,
a university, or research agency, to the extent they may yield reliable
emission factors or formula to calculate emissions factors for certain
types of engines and equipment other than for the large main engines on
drilling ships and drill platforms and for locomotive-sized engines
powering cranes. These studies may be helpful to generate emission
factors for marine coating operations, flares, emissions from drilling
muds, etc. If an emission study is used, the study must cover
representative engines, fuels, and duty cycles.
Fifth, in certain situations, the MARPOL Annex VI engine emission
standards may be used as proxies for emission factors. This option
would be available only for an engine installed on a non-U.S. flagged
vessel that is not part of an engine family that is covered by a USEPA
certificate of conformity but that is MARPOL certified. In this case,
the lessee or operator must indicate the vessel flag as well as engine
size used to determine the standards to use as the proxy emission
factor for that engine. If this approach is used, the plan would also
be required to account for any differences in fuel sulphur limits.\68\
If all fuel used by the subject drilling ships and offshore platforms
is purchased in the U.S., the CAA fuel requirements would apply.
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\68\ Under Annex VI, the NOX engine type
certification is separate and not related to the fuel sulphur
limits. The technical code for certifying Annex VI Regulation 13
engines requires ``suitable'' testing fuel be used and that the
characteristics of the testing fuel be noted for the certification.
Vessels operating in North American/Caribbean Emissions Control Area
(ECA) are all required to use 0.1% sulfur fuel, regardless of the
flag of the vessel and regardless of where the fuel was purchased.
Vessels may also achieve compliance within the ECA by receiving an
Annex VI Regulation 3 trial permit or Regulation 4 equivalency
determination, in lieu of using the 0.1% sulphur fuel. If the MSC
operations associated with the facility are all within the ECA and
the Annex VI Reg13 engine was tested using 0.1% sulfur fuel, there
would be no differences in fuel sulphur limits to account for.
However, it is recognized that the ECA is smaller than the OCS area
impacted by this regulation so vessels may not be using 0.1% sulfur
fuel, and that the Annex Regulation 13 engine may have been
certified using a fuel different from the fuel used during
operations.
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BOEM seeks comment on: (1) Whether this fifth alternative would be
appropriate or is needed, particularly given that the emission factors
used in USEPA's marine and nonroad emission models apply regardless of
flag (i.e., emissions from similar engines in similar use regardless of
whether the engine is on a US or a foreign-flag vessel); (2) how such
an approach would be applied to engines that use Heavy Fuel Oil, since
the NOX Technical Code (NTC) allows engines to be certified
on diesel fuel (which can have relatively high sulfur content); and,
(3) what approach could be taken to estimate pollutants other than
NOX (since there are no MARPOL standards for the majority of
criteria and precursor pollutants) and, if using one of the other
approaches is preferred, whether the NOX emission factors
from those other approaches should be used and this fifth alternative
be not adopted.
Sixth, under the proposed rule, if none of the methods provided in
the first five options above are applicable, for a natural gas-powered
engine of any

[[Page 19755]]

rated capacity, or for a non-road diesel-powered engine with a maximum
rated capacity less than 900 kW, or for a non-engine emissions source,
the lessee or operator could use the appropriate emissions factor from
the USEPA AP 42, Fifth Edition, Compilation of Air Pollutant Emission
Factors, Volume 1: Stationary Point and Area Emissions sources, or any
update thereto, as incorporated by reference at Sec. 550.198(b)(1)(i).
Seventh, if none of the above options are applicable,\69\ the
lessee or operator would be required to conduct stack testing on the
emissions source to determine the appropriate emissions factor. The
data from stack testing could be used only for the engine for which the
stack testing was conducted.
---------------------------------------------------------------------------

\69\ This option is not required as the first alternative
because stack testing is generally very expensive and limits the
flexibility of operators in preparing their plan(s) (because stack
testing is engine-specific).
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If a lessee or operator elects to apply an emissions factor based
on a standard, as allowed under the 5th and 6th alternatives, it must
take appropriate account of the deterioration in performance based on
the age of the equipment and the potential variation of the actual
emissions from the standard to account for the maximum potential
emissions that the emissions source may emit. Given that equipment
tends to operate less efficiently over time, the lessee or operator
should make an appropriate upward adjustment in the emissions estimates
for older equipment (e.g., to reflect emission deterioration over
time). BOEM solicits comments and suggestions on how this might most
appropriately be conducted and the extent to which there are
appropriate, documented, methodologies for making these kinds of
adjustments.
The proposed rule would also require that any time a lessee or
operator revises a plan, including as a part of its resubmissions every
ten years, it must consider the age of the equipment, adjust for any
change in operating efficiency, and provide the associated emissions
factors in its revised or resubmitted plan, as applicable. Also, under
the proposed rule the Regional Supervisor may require a lessee or
operator to use a different emissions factor for any emissions source
or air pollutant if the Regional Supervisor has reason to believe the
selected emissions factor is inaccurate to a material degree or new
information on emissions factors becomes available. The proposed rule
would also provide the Regional Supervisor may require stack testing or
another form of validation to verify the accuracy of an emissions
factor.
Various U.S. manufacturers of non-road and marine diesel engines
produce both domestic and export-only versions of each piece of
equipment. The domestic version is manufactured to comply with USEPA
emissions requirements whereas the export-only version may or may not
comply with USEPA requirements. Domestic versions may, in some cases,
be exported. Manufacturers in other countries also produce, or may in
the future produce, both engines that are certified by the USEPA as
legal for sale in the U.S. and engines that are not. The USEPA provides
emissions factors for such equipment that is certified to be legal for
use in the U.S., and these emission factors apply to an originally-
configured U.S.-certified engine regardless of its marketing path. It
does not test or evaluate the emissions of U.S.-manufactured equipment
intended only for export or foreign-manufactured equipment not intended
for sale in the U.S. For this reason, under the proposed rule, if a
lessee or operator proposes to utilize an engine or equipment that is
manufactured in the U.S. or any other country, but which is not
certified by the USEPA for use in the U.S., the lessee or operator may
not use a USEPA emissions factor intended to apply to the domestic
version of such engine or equipment of the same vintage. Under the
proposed rule, if a lessee or operator proposes to utilize an engine or
equipment on a U.S.-flagged vessel that is not USEPA-certified for use
in the U.S., then that lessee or operator must test the actual
emissions of the proposed engine or equipment and submit data on its
actual emissions. If the lessee or operator claims to use a USEPA
certified engine or equipment, it must submit documentation of that
engine or equipment's certification.
Under the proposed rule, if a lessee or operator's projected
emissions include emissions for a U.S. flagged vessel, then it must
submit documentation of the USEPA-issued Certificate of Conformity for
each mobile source engine.\70\ For MARPOL-compliant foreign-flag
equipment for which no other emissions factor data are available,
MARPOL emissions standards may be used to determine proxy emission
factors where such emissions standards are available (see 5th option,
above).\71\ However, if this source is used, the plan must account for
any differences in the fuel sulphur limits applicable to the fuel being
used for operations and the sulphur limit of the fuel used for emission
testing. All fuel used by the subject drilling ships and offshore
platforms would be required to either be purchased in the U.S. or
comply with applicable CAA fuel emissions requirements, unless the
lessee or operator could demonstrate that it has properly accounted for
any differences in emissions that may result from the use of non-U.S.
fuel. If a lessee or operator proposes to use any engine or equipment
that is neither USEPA-certified nor MARPOL-compliant, then it may not
use an emissions factor intended to apply to a MARPOL compliant engine
or equipment. In that case, the lessee or operator would be generally
required to provide actual emissions test results for the engine.
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\70\ The USEPA requires that all U.S.-flagged vessels must have
engines certified by the USEPA.
\71\ MARPOL emission standards and certification requirements
for Category 3 propulsion engines are similar to those of the USEPA,
and USEPA emission factors appropriately matched to the vintage and
type of engine may be used for such engines.
---------------------------------------------------------------------------

Paragraph 550.205(c)--Facility Emissions
This paragraph is intended to provide a consistent set of criteria
to determine what should be included in each plan with respect to
facilities and their corresponding emissions.
This paragraph would require facility emissions to be reported for
each criteria and major precursor air pollutant in three separate ways.
First, paragraph (c)(1) would require the lessee or operator to
calculate and report the projected annual emissions for each facility
in its plan, itemized by all of the emissions of each emissions source
on or physically connected to each facility. Such calculations should
be done for each year that the plan is proposed to engage in operating
activities, for a period of ten years. Emissions reported under this
subparagraph would include those associated with any emissions source
involved in the construction, installation, operation, or
decommissioning of the facility, based on the maximum rated capacity of
each emission source associated with the facility and using the methods
and procedures specified under paragraphs (a) and (b) of this section.
Second, paragraph (c)(2), would require the lessee or operator to
calculate and report the maximum 12-month rolling sum \72\ of emissions
from each emissions source on or connected to each facility and the
maximum 12-month rolling sum of the emissions from each facility. The
purpose of this latter requirement is to

[[Page 19756]]

identify the peak emissions that would be expected to occur during any
12-month period within the duration of the plan. Third, in paragraph
(c)(3), the proposed rule would require lessees or operators calculate
the maximum projected peak hourly emissions from each emissions source
on or physically connected to each facility and the maximum projected
peak hourly emissions from each facility that would result from the
construction, installation, operation, or decommissioning of the
facility.
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\72\ The plan must include the emissions for the 12 consecutive
month period in which the emissions are projected to be the
greatest, regardless of the calendar year in which those months
occur. All references to 12-month rolling sum are intended to refer
to 12 consecutive month intervals without any overlap.
---------------------------------------------------------------------------

The proposed rule would specify the lessee or operator must
calculate its projected emissions from each emission source, based on
the maximum rated capacity of each engine it proposes to use, or the
capacity that generates the highest rate of emissions. Emissions
information would be required for emissions sources individually and
for the entire facility or facilities. BOEM expects it would implement
this proposed requirement by continuing its current practice whereby
lessees and operators provide information on their emissions in a table
that they submit with their plan.
BOEM intends this requirement to be broad, and accordingly, the
proposed rule also defines ``emissions sources'' and ``facilities''
broadly. (See discussion of definitions of those terms at Sec. Sec.
550.105 and 550.302). The requirement to report facility emissions
exists in the current regulations, but the proposed rule would refine
the requirement. The result of these broad definitions in the context
of this proposed section would be that all sources of emissions
connected to a facility should be accounted for in a plan. Examples of
emissions sources on platforms that a lessee or operator would be
required to report under this proposed section include, but are not
limited to, boilers/heaters/burners, diesel engines, drilling rigs
attached to the seabed, combustion flares, cold vents, fugitives,
glycol dehydrators, losses from flashing, natural gas engines, natural
gas turbines, pneumatic pumps, pressure/level controllers, amine units,
loading losses, tanks, dual fuel turbines, and sources involved in mud
degassing or storage tanks. Examples of sources that would also be
accounted for under this proposed section that normally are not on a
platform include, but are not limited to, drilling rigs, and any other
equipment that is temporarily or permanently connected to any planned
facility. This would include any support vessel (crew, supply, tugs),
pipeline lay barges, pipeline bury barges, derrick barges (installation
of structure), and well testing equipment, while connected or moored to
the facility.
The USEPA concept of PTE, which it defines at 40 CFR 51.301, is
similar to the BOEM concept of facility emissions, in that both PTE and
facility emissions refer to the maximum aggregate capacity of a
stationary source to emit a pollutant under its physical and
operational design. In both cases, this concept includes all emissions
sources attached to a facility but excludes the attributed emissions of
unattached non-stationary sources.\73\ For further details on the
concept and use of PTE in the USEPA context, see ``Potential to Emit: A
Guide for Small Business,'' USEPA, Office of Air Quality Planning and
Standards, Research Triangle Park, NC, EPA-456/B-98-003, October 1998,
available at: https://www3.epa.gov/airtoxics/1998sbapptebroc.pdf.
---------------------------------------------------------------------------

\73\ However, as defined by BOEM, a non-stationary source, such
as a vessel, vehicle or aircraft could also have a potential to
emit.
---------------------------------------------------------------------------

BOEM is considering whether to use the term PTE instead of facility
emissions, and BOEM invites comment on this question.
Paragraph 550.205(d)--Attributed Emissions (i.e., Non-Facility
Emissions)
Proposed Sec. 550.205(d) specifies how emissions from MSCs
described in a plan would be attributed to a facility described in that
plan. The proposed section provides the procedures by which operators
would account for emissions from these MSCs while they are supporting
the operations in the plan. Under the proposed rule, lessees and
operators would be required to calculate both the total emissions that
every MSC in its plan generates and then to calculate the portion of
that total that should be attributed to their facility.
First, for each facility described in a plan, a lessee or operator
would be required to identify the MSCs that would be used to support
that facility. The lessee or operator, to the extent practicable, would
also be required to identify the other facilities each MSC would
support.
Second, for each such MSC, the lessee or operator would calculate
its emissions per trip, from when the MSC leaves its home port until it
returns (i.e., support emissions per trip), irrespective of what other
facilities the MSC may also service. The lessee or operator would be
required to base such calculations on the maximum rated capacity or the
capacity that generates the highest rate of emissions for each
emissions source on the MSC. Having done this, the lessee or operator
would multiply this result by the number of trips the MSC would take in
support of the facility during the 12 consecutive-month rolling maximum
period over which the corresponding facility emissions would be
measured. In addition, each lessee or operator would also have to
determine and report the maximum projected peak hourly emission for
each MSC. If an MSC does not support any other facilities, the proposed
rule would require the lessee or operator to attribute all of these
emissions to the facility the MSC supports. However, if an MSC supports
multiple facilities, the proposed rule would then provide three
alternative methods for calculating the portion of total MSC emissions
that lessees and operators would be required to attribute to their
facility. First, a lessee or operator could, to the extent practicable,
calculate and report the difference between the total support emissions
and the emissions it can document should be reasonably allocated to
another facility. This option would be available to lessees or
operators who know detailed information about the routes of the MSCs in
their plans and what other facilities each MSC would support. Second,
if the first method is impracticable but the lessee or operator knows
the number of facilities supported by any given MSC (but not their
locations or the routes of the MSC), the operator could divide the
total support emissions by the lowest number of the facilities the
operator reasonably determines the MSC will serve on a typical trip,
including the facilities described in its plan. If neither of these two
methods is practicable, the rule would allow operators to calculate and
report the greater of either (1) the emissions that would be generated
by the MSC traveling round trip between its port or home base and the
facility, or (2) the emissions from the MSC operating within 25 statute
miles of the facility. Finally, the proposed rule would allow lessees
or operators the ability to elect to attribute the total support
emissions of any vessel or vehicle to their facility if they decide not
to allocate the emissions among facilities.
The proposed rule includes the options described above because a
lessee or operator may not know, at the time of plan submittal, which
facilities an MSC will support. The intent is to provide these
alternatives for allocating support vessel emissions in situations
where it would otherwise be impracticable to do so. The options in the
proposed rule are intended to account for the variety of practices that

[[Page 19757]]

could occur on the OCS and the ability to know the particular operation
of an MSC at the time of plan submittal.
With respect to proposed Sec. 550.205(d)(7), although that
requirement is only one of the assumptions that are to be used in
calculating the MSC emissions, the provision is intended to clarify it
would not be appropriate to calculate the emissions only for one
source, in the event an MSC had multiple sources of relevant emissions.
The rule is intended to clarify the maximum rated capacity requirement
applies to each source on every MSC, in any situation where an MSC has
multiple emissions sources.
Further, the proposed rule would provide that if BOEM questions the
lessee or operator's determination of the attributed emissions, the
Regional Supervisor may require additional documentation to support
their findings and may direct them to make changes, as appropriate.
Finally, just as BOEM is considering using the term PTE in place of
the term facility emissions, BOEM is also considering using USEPA's
term secondary emissions (as defined in 40 CFR 51.301) in place of
attributed emissions. BOEM welcomes comment on this question.
Paragraph 550.205(e)--Projected Emissions (i.e., Combined Facility and
Attributed Emissions)
This paragraph is intended to provide a detailed, consistent set of
criteria to determine what should be included in each plan with respect
to projected emissions of facilities and MSCs.
Proposed Sec. 550.205(e) would require a lessee or operator to
calculate the maximum 12 month rolling sum of projected emissions of
each criteria and major precursor air pollutant for each of its
facilities. This would represent the sum of the facility emissions for
the 12-month rolling maximum period reported under (c)(2) of this
section and attributed emissions reported under (d)(6) of this section
for the same period. Pursuant to the criteria set forth in proposed
Sec. 550.303(d), the lessee or operator would also be required to
determine whether the projected air emissions from each facility would
need to be consolidated with those of other facilities.
If any of a lessee's or operator's proposed facilities would be
located in such a manner (as defined in Sec. 505.303) as to
potentially constitute proximate activities with a pre-existing
facility, or a facility that was previously approved but not yet
constructed, the proposed rule would require any such facility to be
identified in the plan. If the lessee or operator would be required to
consolidate emissions from multiple facilities, then it would need to
provide projected emissions information for each facility as well as
the complex total emissions for all of consolidated activities.
In addition, the proposed rule would also require every lessee or
operator to calculate and report the projected annual emissions for its
facilities for each year in which it intends to operate, as well as the
maximum peak hourly emissions for each facility and the corresponding
attributed emissions.
Paragraph 550.205(f)--Emission Reduction Measures (ERM)
The purpose of this paragraph is to describe in general terms the
information that must be included in a plan regarding the types and
purpose of various emission reduction measures that are proposed in a
plan and what reductions the lessee or operator expects to achieve from
these proposed measures.
Under the proposed rule, a lessee or operator may elect to propose
ERM in its plan to ensure that its projected emissions are under the
EETs described in proposed Sec. 550.303. Whether an operator elects to
propose ERM or whether the proposed rule would require it, this section
would require that such proposed measures be reported in the plan. This
element of the proposed rule is consistent with current GOM Region
practice. It would specify that the lessee or operator must provide a
description of all proposed ERM, including the affected emissions
source(s); the emissions reduction control technologies, procedures,
and/or operational limits; the emission control efficiencies; the
projected quantity of reductions to be achieved; and, any monitoring or
monitoring system the submitter proposes to use to measure or evaluate
the associated emissions. The rule would further clarify the lessee or
operator must be able to demonstrate that all of the ERM described in
the plan meet the applicable substantive requirements in proposed Sec.
550.309.
BOEM expects lessees or operators are likely to consider
operational controls to reduce emissions for many sources, for example
limiting the hours of operation, reducing engine power, etc., in order
to bring their projected emissions within the EETs. This proposed
section would require the application of such operational controls to
be documented in the plan, which would require review by the Regional
Supervisor, and approval only when the ERMs are demonstrated to
maintain and not compromise the safety of operations. Other sections of
the proposed rule, such as proposed Sec. Sec. 550.309 and 550.311,
would subject each proposed emission reduction measure to monitoring,
reporting, and verification.
Geological sequestration of pollutants under the seabed is another
potential emission reduction measure that has not yet been considered.
BOEM would welcome feedback on the extent to which stakeholders
consider this to be a potentially viable and effective control
mechanism, either in conjunction with or as an alternative to other
measures.
Paragraph 550.205(g)--Modeling Information
This paragraph is intended to provide a detailed, consistent set of
information and criteria to determine what should be included in each
plan submitted to BOEM with respect to the proposed modeling of air
emissions associated with a plan's projected operations.
If a lessee or operator conducts modeling in support of its plan,
then the proposed rule would require the lessee or operator to provide:
A table(s) of the appropriate and relevant maximum projected air
pollutant concentrations over any area(s) of any State(s) and Class I
area(s) including the most affected attainment area(s) and the most
affected non-attainment area(s), as applicable; the maximum projected
concentrations resulting from the projected emissions for each of the
facilities, by criteria air pollutant and major precursor air
pollutant, for the corresponding averaging time(s) (e.g., 1-hour, 3-
hour, 8-hour, 24-hour, annual, etc.) specified in the tables in 40 CFR
51.165(b)(2), 40 CFR 52.21(c), and 40 CFR part 50; a list of the
inputs, assumptions and default values used for modeling, including the
source and justification for meteorological information; the name and
version of the model(s) used; a modeling report, including the modeling
results (unless already provided and the projected emissions are the
same or lower); and, for each MSC, the distance from the facility or
facilities in the plan to the relevant home port or base. All of this
information is necessary so BOEM can properly evaluate and validate the
results of the modeling.
Under the proposed rule, if a lessee or operator would be required
to model projected emissions, and the lessee or operator has previously
submitted a modeling report and/or modeling results to the Regional
Supervisor, then the lessee or operator may provide a reference to such
report and/or results, rather than resubmit a modeling report and/or
modeling results, provided the projected emissions are the same or

[[Page 19758]]

lower than in the previously submitted report(s) or results.
Paragraph 550.205(h)--Requirements Applicable to Specific Air
Pollutants
550.205(h)(1)--Nitrogen and Sulphur Oxides (NOX and
SOX)
Because the intent of the proposed rule is to evaluate the maximum
potential effect that could occur with respect to the implementation of
any given plan, the proposed rule would clarify a lessee or operator
must utilize data for NOX and SOX whenever
possible or reasonable estimates thereof. Projected emissions of
NOX would need to include emissions of nitrogen oxide and
NO2, as well as any other oxides of nitrogen for which data
are available. Similarly, any projected emissions of SOX
would need to be reported, including but not limited to the emissions
of SO2. Only in the event that data on the broader emissions
of NOX or SOX are not available, would the
proposed rule specify a lessee or operator could utilize data on the
sum of nitrogen oxide and NO2 emissions as a substitute for
NOX and data on SO2 emissions as a substitute for
SOX.
550.205(h)(2)--PM10 and PM2.5
Because the USEPA has replaced ``total suspended particulates''
with two separate kinds of pollutants, a lessee or operator would be
required to provide data and information on both PM10 and
PM2.5, whenever such information is available for any given
emissions source, and to evaluate each separately under every
applicable standard in all cases where it is possible to do so. This
should not present an issue, since the split in the PM classification
has existed for quite a few years. Only in the rare event that
available data for PM are not separately reported for both
PM10 and PM2.5 for any given emissions source,
would the proposed rule require lessees and operators to perform their
analysis of PM2.5 emissions utilizing PM10 data
for the emissions threshold analysis and for modeling purposes.
However, the proposed rule specifies a lessee or operator must
separately identify all PM2.5 and PM10 emissions
in its plan and a plan that fails to contain separate emission
exemption threshold and modeling data for each pollutant will not be
considered complete. Because there are separate SILs, AAIs and NAAQS
for PM10 and PM2.5, and also because the
PM2.5 evaluations require an evaluation of the ambient
impacts of both direct and secondary PM2.5, a plan may not
be submitted that includes and addresses only PM10
emissions. If the separate data are not available, the lessee or
operator must utilize the data for PM10 for its analysis of
PM2.5, (assuming the PM2.5 is as high as the
PM10).
Finally, the proposed rule clarifies that all reporting of
PM2.5 must include the sum of filterable and condensable PM,
if such information is available, in order to be complete.
550.205(h)(3)--Hydrogen Sulfide (H2S)
To properly estimate the potential emissions of SOX
under this proposed paragraph, all emissions of SOX that
result from the flaring of H2S would need to be included in
the projected emissions of SOX reported and analyzed as part
of each plan. Under the proposed rule, if projected emissions of
H2S will potentially exceed the USEPA's Significant
Emissions Rate for H2S, as defined in 40 CFR
52.21(b)(23)(i), the lessee or operator must report the nature and
extent of these emissions and their likely impact as part of its plan.
The proposed rule would specify that reporting of H2S
would be required to follow the USEPA's Oil and Natural Gas Sector New
Source Performance Standards and National Emission Standards for
Hazardous Air Pollutants Reviews. These are described more specifically
in ``Oil and Natural Gas Sector: New Source Performance Standards and
National Emission Standards for Hazardous Air Pollutants Reviews,'' 77
FR 49489, RIN 2060-AP76, October 2012.
Aside from the proposed Sec. 550.205, BOEM is also proposing to
modify Sec. Sec. 550.215 and 550.245 regarding H2S such
that if a lessee or operator proposes to flare gasses containing a
potentially significant amount of H2S, it must separately
identify this activity in the plan and separately identify the
resulting emissions of SOX.
550.205(h)(4)--Methane (CH4)
This rule implements BOEM's statutory authority under OCSLA section
5(a)(8) to regulate OCS air pollutant emissions from oil and gas
operations in order to prevent adverse, localized air quality effects
to adjacent States; since there are no significant localized air
quality effects on the States associated with the emissions of methane
from OCS facilities, BOEM is not proposing to regulate methane
emissions in this context.
Under the proposed rule, the analysis or reporting of methane
emissions would not be required unless specifically directed to the
contrary. Consistent with current BOEM policy, any reference in these
proposed regulations to major precursor air pollutants would exclude
methane, because the USEPA does not include methane in the definition
of VOCs and does not require a methane analysis of ground level ozone
formation for offshore facilities; both because methane has not
historically been considered a significant precursor air pollutant with
respect to distances and transport times relevant to BOEM regulation of
offshore activities; and because the USEPA has not elected to formally
classify methane as a precursor pollutant for O3. BOEM
solicits comments on this proposed exclusion and on how BOEM should
address the effects of methane emissions on secondary O3
formation and under what circumstances it would be appropriate, in the
event it decides to do so.
550.205(h)(5)--Ozone (O3)
Over the past 35 years, extensive scientific evidence has
increasingly demonstrated the importance of controlling O3,
and the significant potential harm this pollutant can cause.
Additionally, as a result of improvements to single source
photochemical modeling capabilities, it is now possible to evaluate
much more accurately how the emissions of O3 precursors may
contribute to O3 formation and how this may affect the air
quality of the States. Reflecting the changes in the NAAQS and the
improvement in modeling capabilities that have occurred over the past
35 years, BOEM is now proposing to evaluate O3 directly for
compliance with the NAAQS.
The proposed rule would not immediately require analysis or
reporting of O3. Rather, once the new emissions exemption
studies have been completed, new EETs would likely be established to
address O3 impacts to the State. Proposed paragraph
550.304(b) details the circumstances when O3 modeling would
be required. Comments may be submitted as to how this would best be
accomplished and at what point in time the implementation of these new
standards would be most appropriate.
550.205(h)(6)--Lead (Pb) and Ammonia (NH3)
Ammonia (NH3) has been identified as a potentially
significant precursor air pollutant for PM2.5. The proposed
rule would require reporting of NH3 emissions, for any given
source, if that information is available. Such a determination would be
based on whether there are published manufacturer specifications of
emissions factors for NH3, whether such information could be
obtained from the USEPA, or whether it could be obtained or could be
derived from another

[[Page 19759]]

recognized source, such as utilizing a mass balance approach.
Lead (Pb) is a CP for which NAAQS have been established. For this
reason, consistent with the OCSLA mandate, like NH3,
reporting of Pb emissions would be required to the extent relevant
information is available or could be derived from another recognized
source, such as utilizing a mass balance approach.
Because of BOEM's obligation under OCSLA to ensure compliance with
the NAAQS, BOEM is proposing that all emissions of NAAQS pollutants
should normally be reported. If the lessee or operator intends to use a
source known to emit a potentially significant amount of Pb or
NH3, then it must obtain a reasonable estimate of the
associated Pb or NH3 emissions. For that reason, the
proposed rule specifies that zero emissions for Pb and NH3
may be assumed only in the situation where relevant data are not
available and neither the lessee or operator nor BOEM have a reason to
anticipate that the emissions could be potentially significant.
Paragraph 550.205(i)--Distance Calculations
To determine the appropriate EET for each facility in a plan, the
proposed rule would retain the requirement that the lessee or operator
provide the distance in statute miles, from the shoreline, until such
time as the new thresholds are established in 2020. Because the
proposed rule intends to retain the current exemption methodology for a
period of time and then replace that methodology,\74\ two distance
measures would be proposed in this rule. As is currently required by
BOEM regulations, the first would be the distance from shore, as
measured in a straight line from the site of each facility to the
closer of the mean high water mark of a State or, on the Pacific coast,
the mean higher high water mark, or the nearest Class I area of any
State. The second would be the distance from a State's seaward
boundary. For each facility described in the plan, the lessee or
operator would be required to calculate and provide the distance in
statute miles, as measured in a straight line from the site of the
facility to the closest point at which the OCS borders any State, at
the seaward boundary.
---------------------------------------------------------------------------

\74\ As discussed in the context of proposed Sec. 550.303(c),
the proposed rule would continue to retain the shoreline as the
point at which emissions are evaluated until such time as the new
scientific studies have been completed and new exemption thresholds
have been defined. At that time, BOEM would evaluate all emissions
at the SSB and any facility that generates emissions in excess of a
SIL at the SSB would have to apply ERM. For this reason, the
distance calculation used by the exemption formulas would be the
distance to shore, in the first instance, and the distance would be
the distance to the SSB, in the second instance.
---------------------------------------------------------------------------

Paragraph 550.205(j)--Documentation
Unlike the current regulations, which do not specify any
documentation or data retention requirements, the proposed rule
outlines the data and recordkeeping requirements BOEM proposes to
require to facilitate BOEM's evaluation and review of each plan and the
corresponding operational activities that result from each plan. This
information would be used to verify compliance with BOEM regulatory
requirements and to ensure that compliance with such requirements
continues on an ongoing basis.
The proposed rule would require lessees or operators to collect,
create, and maintain records or any data or information establishing,
substantiating, and verifying the basis for all information, data, and
resources used to calculate their projected emissions under proposed
section 550.205. The proposed rule would require documentation of the
emissions factors used and retention of any appropriate certifications,
citations, methods, and procedures used to obtain or develop emission
factors. The proposed rule would require collection and maintenance of
all documentation pertaining to the modeling analysis, if applicable,
including all references and copies of any referenced materials, as
well as any data or information related to any ERM lessees or operators
propose or implement. Under the proposed rule, all such information
would need to be provided to BOEM, though the Regional Supervisor would
be able to waive this requirement for good cause or if BOEM is able to
obtain the necessary information from an independent source.
Paragraph 550.205(k)--Compliance With Subpart C
The proposed rule would require lessees and operators to provide a
description of how they will comply with proposed section 550.303 when
the projected emissions generated by the proposed plan activities
exceed the respective EETs. The proposed rule would require lessees and
operators to make this determination using the formulas in proposed
paragraph 550.303(c). If the lessee or operator would be subject to the
requirement to monitor and report its actual emissions in accordance
with section 550.311, then the description must address how it proposes
to monitor its emissions.
Paragraph 550.205(l)--Reporting
The proposed rule would require lessees and operators to submit
data and information in a format and using the forms specified by BOEM.
They would be required to submit information in an electronically-
readable spreadsheet, such as a Microsoft Excel file on a compact disc,
unless otherwise directed by the Regional Supervisor. The purpose of
this requirement is to facilitate the evaluation of data by automated
processes and systems. Under the current arrangement, data are
submitted to BOEM in approved Excel spreadsheets. Although the proposed
rule does not specify a specific format for electronic forms, it is
likely the current spreadsheets will continue to be used for the
foreseeable future.\75\
---------------------------------------------------------------------------

\75\ Currently, BOEM utilizes OMB-approved forms BOEM-0134 and
BOEM-0135 for this purpose. The forms are being revised in
connection with this rulemaking. BOEM also solicits comments on the
proposed new forms, in terms of their usefulness, readability,
complexity and completeness.
---------------------------------------------------------------------------

The USEPA is currently working on an E-Enterprise solution for
emissions data collection, whereby facilities (or companies) would
report emissions data through a central place for distribution to
USEPA, the States, and others. Since BOEM is proposing direct facility
reporting as well, BOEM may elect to partner on this E-Enterprise
solution for supporting BOEM's needs alongside those of the USEPA. This
approach may be more efficient both for the regulated entities as well
as for USEPA and BOEM to use and share the data. BOEM welcomes comment
on this alternative and whether there may be any impediments or
complications should BOEM wish to move in this direction.
If lessees and operators elect to transmit the information to BOEM
electronically, such as by email, then they would be required to use a
delivery medium or transmission method authorized by BOEM. The purpose
of this requirement is to ensure any data or information provided to
BOEM is provided in a secure and safe manner and such information is
not submitted in a way (e.g., email) that could be intercepted or
manipulated by third parties. DOI has established standards and
requirements for the secure transmission of data on an approved
technology platform and BOEM intends to adhere to DOI requirements
(although it may do so using a BOEM-specific transmission mechanism,
such as the Technical Information Management System Web-based
application, abbreviated TIMS-Web).

[[Page 19760]]

Paragraph 550.205(m)--Additional Information
Proposed Sec. 550.205(m) would set out the circumstances under
which a lessee or operator would be required to include information
about emissions from aircraft and from those onshore support facilities
for which the lessee or operator does not have an USEPA or State agency
air quality permit (i.e., ``a non-permitted onshore facility''). The
proposed requirement would be triggered when the modeling of air
emissions indicates that a plan's proposed emissions would cause an
increase in the ambient air quality at any receptor location that
exceeds 95% of a SIL. If an operator or lessee would be required to
report emissions from any aircraft or non-permitted onshore support
facilities and they support multiple OCS facilities, the lessee or
operator would be required to allocate their emissions in an
appropriate manner similar to that described for MSCs. Under such
circumstances, a lessee or operator would be required to include such
emissions in the information required under proposed section 550.205
and proposed subpart C. The proposed rule would also permit the
Regional Supervisor to require such additional data or information
related to these sources as is necessary to demonstrate the plan's
compliance with subpart C of this part, and/or applicable federal laws
related to the protection of air quality within BOEM jurisdiction.
Paragraph 550.205(n)--Requirements for Plans To Be Deemed Submitted
In order for a plan to be deemed submitted, all of the required air
quality data and information would be required to be submitted to BOEM
in accordance with the requirements of this part. BOEM would not
initiate its review of the air quality component of any plan until all
of the necessary information and documentation is complete. To
facilitate this, the proposed rule would specify that a plan would not
be deemed submitted in accordance with the requirements of Sec.
550.231 or 550.266 of this part until:
(1) All of the requirements of this section have been completed;
(2) The lessee, or operator, has completed the AAI analysis as
specified in Sec. 550.307(b) of this part, if it is required; and
(3) The lessee, or operator, has completed any other analysis
required by subpart C of this part.
Section 550.211--What must the EP include?
Paragraph 550.211(c)--Drilling Unit
The current regulation at Sec. 550.211(c) includes a provision
that requires a description of the ``fuels, oil and lubricants that
will be stored on the facility.'' The regulations state the word
``facility'' is defined in Sec. 550.105. However, the section to which
the current regulations refer no longer exists in BOEM's regulations.
That provision was originally in the regulations administered by BOEM's
predecessor before it was divided into BOEM and BSEE, and was
subsequently moved into the BSEE regulations at Sec. 250.105.
The original definition of the term ``facility,'' to which the
references in Sec. Sec. 550.211 and 550.241 refer, was: ``a vessel, a
structure, or an artificial island used for drilling, well completion,
well-workover, or production operations.'' Because this definition of
facility no longer exists, BOEM is proposing to add this definition
back into Sec. Sec. 550.211 and 550.241 where its use remains
applicable, with minor modifications for clarity. No substantive change
to Sec. 550.211 or 550.241 is being proposed.
For the purpose of this section, the term facility would mean any
installation, structure, vessel, vehicle, equipment or device that is
temporarily or permanently attached to the seabed of the OCS, including
an artificial island used for drilling, well completion, well-workover,
or other operations.
Section 550.212--What information must accompany the EP?
This section describes the information that must be included in an
EP. The change to the proposed rule for this section would update the
cross-reference in Sec. 550.212(f) from Sec. Sec. 550.218 to 550.205,
since the air quality requirements of Sec. 550.218 are proposed to be
relocated there.
Section 550.215--What hydrogen sulfide (H2S) information
must accompany the plan?
Paragraph 550.215(d)(2)--Hydrogen Sulfide
Under the proposed rule, if the H2S emissions are
projected to affect any location within a State in a concentration
greater than 10 parts per million, the modeling analysis would need to
be consistent with the USEPA risk management plan methodologies
outlined in 40 CFR part 68. The only change made with this revision
would be that the concentration of 10 parts per million would be
measured at any point within the State including any point landward of
the SSB, not only onshore, as is currently the case.
Paragraph 550.215(e)--Hydrogen Sulfide
As explained above in the discussion of Sec. 550.205, the proposed
rule would amend this section and section 245 by adding a paragraph in
each to specify flaring of any gasses containing a potentially
significant amount of H2S would be required to be separately
identified in the plan, along with the resulting emissions of
SOX.
Section 550.218--What air emissions reporting must accompany the
plan?--Removed and Reserved
Sections 550.218 and 550.249 in the current regulations set forth
the air quality reporting requirements of subpart B for exploration
plans and development plans, respectively. All of the substantive
requirements from these two sections would be consolidated into the new
proposed section 550.205 and modified as discussed above. Accordingly,
Sec. Sec. 550.218 and 550.249 would become reserved.
Section 550.224--What information on support vessels, offshore
vehicles, and aircraft must accompany the plan?
Paragraph 550.224(a)--General
Current regulations require plans to include a description of the
vessels, offshore vehicles, and aircraft lessees and operators would
use to support their exploration activities (Sec. 550.224(a)) or their
development and production activities (Sec. 550.257(a)). The proposed
rule would reword paragraph (a) of the proposed sections for clarity
and to incorporate the term MSC, proposed for definition in this rule,
but the meaning and intent of these paragraphs would not be changed.
The proposed rule would retain the current requirement to include in
the description an estimate of the storage capacity of the fuel tanks
and the frequency of visits to the facilities in connection with any
proposed activities.
Paragraph 550.224(b)--Air Emissions
Paragraph (b) of both the current paragraphs (Sec. Sec. 550.224(b)
and 550.257(b)) requires plans to include information regarding air
emissions from vessels, vehicles, and aircraft described in the plan.
The proposed rule would replace this paragraph with a cross-reference
to proposed Sec. 550.205. That proposed section, described above,
would provide details about what emissions information for MSCs must be
included in a plan. However, that proposed section would not generally
require information on aircraft

[[Page 19761]]

emissions. As explained above, aircraft emissions contribute only a
small fraction of emissions, and aircraft emissions information is
especially burdensome to collect. Accordingly, BOEM believes it is not
prudent to require lessees and operators report aircraft emissions in
most cases. The proposed rule would normally only require general
information about aircraft used in a plan under proposed paragraph (a),
since it is necessary for the Regional Supervisor to verify whether
emissions from these sources may contribute to exceeding an emission
exemption threshold or an AAQBS. In some limited circumstances, where
the emissions of aircraft may be determinative of whether the plan does
or does not cause a significant impact to any State or tribe, the
reporting of aircraft emissions may be required, as described in
proposed Sec. 550.205(m).
Section 550.225--What information on the onshore support facilities
must accompany the plan?
Paragraph 550.225(b)--Air Emissions
The current paragraph (b) of both Sec. Sec. 550.225 and 550.258
requires lessees and operators to provide in their plans a description
of the source, composition, frequency, and duration of the air
emissions likely to be generated by the relevant onshore support
facilities. The proposed rule would not substantively change this
requirement, but the proposed rule would revise it for clarity. The
proposed rule would delete the parenthetical text in the current
paragraphs--``attributable to your proposed exploration activities''
and ``attributable to your proposed development and production
activities''--in order to avoid confusion with the use of the term
``attributed emissions'' in proposed Sec. 550.205.
The proposed rule would limit the current requirement for onshore
emissions sources in order to reduce unnecessary reporting and focus
reporting requirements on areas with the greatest potential impact.
BOEM currently requires reporting of onshore support facility emissions
as may be necessary for the Regional Supervisor to determine whether
emissions from these sources may contribute to exceeding an EET or an
AAQSB, as described in the preamble section on proposed Sec.
550.205(m). This requirement in the current regulations is based on the
premise that there may be some circumstances where the amount of air
pollution generated by onshore support facilities, taken in conjunction
with the offshore emissions associated with OCS operations, could have
a potentially significant impact to the air quality of the States.
However, BOEM believes that the requirement can be made more
appropriately tailored to limit unnecessary reporting, while still
incorporating select onshore emissions information in appropriate
circumstances. As described more fully in the preamble discussion of
proposed Sec. 550.205(m), the proposed rule would collect information
on onshore support emissions if two specific criteria are both met: (1)
If a plan which is already required to conduct modeling results in
incremental increases in concentration of a pollutant that are greater
than 95 percent of the value of a SIL (this is the same criteria that
applies to the inclusion of aircraft); and (2) if the relevant onshore
support facilities are not already permitted by the USEPA or a relevant
State authority. The goal of this proposed provision is to incorporate
significant data that may contribute to OCS permitted activity
affecting the air quality of the states but to avoid collecting
unnecessary information. BOEM solicits comments on this proposal, both
with respect to whether gathering data on onshore support facilities is
necessary and/or appropriate and what criteria should be used to
determine the circumstances under which data about onshore support
facility emissions should be collected.
BOEM uses the information that would be required in this paragraph
for the analysis of cumulative impacts it performs under NEPA. The
proposed rule would also provide that the information regarding onshore
support facilities would only be required by BOEM if it is not
available from another agency. BOEM can obtain some of the information
for proposed and existing onshore support facilities for use in its
NEPA or other environmental analyses through the USEPA or other air
quality agencies.
BOEM solicits comments on what types of onshore facilities should
be identified and reported with respect to their air emissions and how
best to evaluate their emissions in the context of the AQRP.
Section 550.241--What must the DPP or DOCD include?
Paragraph 550.241(c)--Drilling Unit and Paragraph 550.241(d)--
Production Facilities
The change proposed here is analogous to the change proposed at
Sec. 550.211. The current regulations at Sec. 550.241(c) and (d)
include provisions that require a description of drilling units and
production facilities in a DPP or DOCD. This description includes
``fuels, oil and lubricants that will be stored on the facility'' or
``the estimated maximum quantity of fuels and oil that will be stored
on the facility,'' respectively. The current regulations state the word
``facility'' is defined in Sec. 550.105(3). However, the section to
which the current regulation refers no longer exists in BOEM's
regulations. That provision was originally in BOEM's predecessor's
regulations before it was divided into BOEM and BSEE and was
subsequently moved into the BSEE regulations at Sec. 250.105.
The original definition of the term facility, to which the
reference in Sec. 550.241 refers, was: ``a vessel, a structure, or an
artificial island used for drilling, well completion, well-workover, or
production operations.'' Because this definition of facility no longer
exists, BOEM is proposing to add this definition back into Sec.
550.211(c) and in Sec. 550.241, with minor modifications for clarity.
No substantive change to Sec. 550.241 is being proposed.
For the purpose of this section, the term facility would mean any
installation, structure, vessel, vehicle, equipment or device that is
temporarily or permanently attached to the seabed of the OCS, including
an artificial island used for drilling, well completion, well-workover,
or other operations.
Section 550.242--What information must accompany the DPP or DOCD?
This section describes the information that would be required to be
included in a DPP or DOCD. The change to the proposed rule for this
section would update the cross-reference in Sec. 550.212(g) from
Sec. Sec. 550.249 to 550.205, since the air quality requirements of
Sec. 550.249 are proposed to be relocated there.
Section 550.245--What hydrogen sulfide (H2S) information
must accompany the plan?
Paragraph 550.245(d)(3)--Hydrogen Sulfide Emissions
See the discussion for Sec. 550.215(d)(2).
Paragraph 550.245(e)--Hydrogen Sulfide
See the discussion for Sec. 550.215(e).
Section 550.249--What air emissions reporting must accompany the plan?
See the discussion for Sec. 550.218.
Section 550.257--What information on support vessels, offshore
vehicles, and aircraft must accompany the plan?
Paragraph 550.257(a)--General and Paragraph 550.257(b)--Air Emissions
See the discussion for Sec. 550.224.

[[Page 19762]]

Section 550.258--What information on the onshore support facilities
must accompany the plan?
Paragraph 550.258(b)--Air Emissions
See the discussion for Sec. 550.225.
Section 550.280--How must I conduct activities under the approved EP,
DPP, DOCD, RUE, pipeline ROW, or lease term pipeline application?
The proposed rule would modify the title of this proposed section
from ``How must I conduct activities under the approved EP, DPP, or
DOCD?'' to ``How must I conduct activities under the approved EP, DPP,
DOCD or RUE, pipeline ROW, or lease term pipeline application?'' In
addition, the proposed rule would modify paragraph (a) of the current
regulations, which specifies that a lessee or operator must conduct all
of its activities in accordance with an approved EP, DPP, or DOCD and
any approval conditions. This provision would be modified to clarify
that a lessee or operator may not install or use any facility,
equipment, vessel, vehicle, or other emissions source not described in
the approved EP, DPP, DOCD, or application for RUE, pipeline ROW, or
lease term pipeline and that a lessee or operator may not install or
use a substitute for any emissions source described in an EP, DPP,
DOCD, or application for a RUE, pipeline ROW, or lease term pipeline
without prior BOEM approval.
Section 550.284--How will BOEM require revisions to the approved EP,
DPP, DOCD, or application for a RUE?
Paragraph 550.284(a)--Periodic Review
The proposed rule would modify the title of the section from ``How
will BOEM require revisions to the approved EP, DPP, or DOCD'' to ``How
will BOEM require revisions to the approved EP, DPP, DOCD or
application for a RUE?''
Paragraph (a) of the current section specifies the Regional
Supervisor will periodically review the activities conducted under an
approved EP, DPP, or DOCD and the frequency and extent of this review
is based upon changes to ``available information and onshore or
offshore conditions.'' The proposal would modify this paragraph to
clarify that the frequency and extent of the review may be based on any
changes in applicable law or regulation as well. Existing Sec.
550.284(b) allows the Regional Supervisor to require modifications to
plans based on such a review. The proposed rule would not change this
paragraph. As discussed below, proposed Sec. 550.310(c) would
complement the proposed change to Sec. 550.284(a) by making explicit
that the Regional Supervisor may require a lessee or operator to submit
a revised plan when an applicable AAQSB changes. BOEM does not
anticipate that it would invoke this provision except in extraordinary
circumstances and, even under those extraordinary circumstances, it
would rarely, if ever, require the resubmission of a plan under this
provision more frequently than every ten years.

C. 30 CFR Part 550, Subpart C

Subpart C is being replaced in its entirety with a new subpart C
dedicated to air pollution prevention and control.
Section 550.301--Under what circumstances does this subpart apply to
operations in my plan?
This section would specify that the proposed subpart applies to
those areas of the OCS where DOI has authority to regulate air
emissions pursuant to section 5(a)(8) of the OCSLA, 43 U.S.C.
1334(a)(8), as amended, and jurisdiction pursuant to section 328(b) of
the CAA, 42 U.S.C. 7627(b), as amended. This section explains the
proposed subpart would apply to all plans related to facilities on the
relevant areas of the OCS, regardless of the type of plan (EP, DPP, or
DOCD or application for a RUE, pipeline ROW, or lease term pipeline).
The section would also state that the subpart covers existing
facilities in the relevant areas.
Section 550.302--Acronyms and Definitions Concerning Air Quality
Paragraph (a) of the proposed rule would update the acronym list
used to identify those acronyms that are relevant to the proposed rule.
In addition, the proposed rule would clarify that the definitions
proposed to be added or revised in proposed Sec. 550.302 are meant to
apply only to Sec. 550.205 of subpart B and all of subpart C.
Deleted Definitions
The following three terms in the current definitions Sec. 550.302
would be removed from the list of definitions in proposed Sec.
550.302: ``source,'' ``temporary facility,'' and ``volatile organic
compound.'' The proposed rule would move the term ``source,'' renamed
``emissions source,'' from Sec. 550.302 into proposed Sec. 550.105,
because it would be used in portions of part 550 outside of subpart C.
The term ``temporary facility'' would be replaced with a new term
``short-term facility'' (although the meaning and purpose of the term
would be similar). The proposed rule would not define the term
``volatile organic compound,'' since other CPs and precursor pollutants
would also not be defined in the regulations and because BOEM applies
the common meaning of this term, as used by the USEPA and other federal
agencies.
New or Revised Definitions
Paragraph (b) would list the definitions used in subpart C, as
follows.
Air Quality Control Region (AQCR)
AQCR would be newly defined to mean ``an interstate area or major
intrastate area, which the USEPA deems appropriate for assessing the
regional attainment and maintenance of the primary or secondary
national ambient air quality standards described in 42 U.S.C. 7409, as
identified under 40 CFR part 81, subparts A and B, Designation of Air
Quality Control Regions.''
Ambient Air Increments (AAIs)
AAIs would be newly defined to mean ``the national standards for
Ambient Air Increments set out in the table in 40 CFR 52.21(c), as
amended.'' These are national ambient air benchmarks that represent the
maximum increase in pollutant concentrations allowed for an onshore
area of a State designated by the USEPA as a Class I, Class II, or
Class III area. Depending on the level of the AAIs, various ERM may be
required by BOEM under subpart C. In the current BOEM regulations, the
AAIs are referred to as the MACIs, as set out in the table in the
current regulation at 30 CFR 550.302.
Ambient Air Standards and Benchmarks (AAQSB)
AAQSB would be newly defined to refer collectively to all of the
standards and benchmarks referenced in this proposed subpart. These
would include the SILs, in 40 CFR 51.165(b)(2) (pursuant to 42 U.S.C.
7401 et seq.); the AAIs, as set out in the table in 40 CFR 52.21(c)
(pursuant to 42 U.S.C. 7473); and the primary and secondary NAAQS
defined in 40 CFR part 50 (pursuant to 42 U.S.C. 7409).
Attainment Area
The current regulations define this term in Sec. 550.302, and the
proposed rule would revise the definition. The proposed rule would
modify the definition of attainment area to mean ``for any given
criteria air pollutant, a geographic area, which is not designated by
the USEPA as being a designated non-attainment area, as codified at 40
CFR part 81 subpart C.'' Thus, any area not specifically listed by the
USEPA as a designated non-attainment area would

[[Page 19763]]

be classified as an attainment area under this proposed rule, including
areas that the USEPA's regulations refer to as attainment, maintenance,
unclassifiable, or unclassifiable/attainment as well as areas that have
not yet been designated because the two-year period to complete such
designations after revision of a NAAQS has not yet passed. The proposed
definition would also clarify that the same area may constitute an
attainment area for one criteria air pollutant and a designated non-
attainment area for another criteria air pollutant (see definition of
non-attainment area). Second, because there may be multiple NAAQS
averaging times for each CP, any given area may be attainment for one
pollutant for one averaging time and non-attainment for the same
pollutant over a different averaging time. Third, this definition would
clarify that the term attainment area, as used by BOEM, is intended to
include onshore unclassifiable areas (i.e., areas that cannot be
classified as attainment or designated non-attainment areas) or any
other areas that the USEPA has not explicitly classified as designated
non-attainment.
Attributed Emissions
This new term would be defined to mean ``for any given criteria or
precursor air pollutant the emissions from MSCs, operating above the
OCS or State submerged lands, that are attributed to a facility
pursuant to the methodology set forth in Sec. 550.205(d), for the
period over which the corresponding facility emissions are measured.''
BOEM intends for this proposed definition to encompass the emissions
that are generated from non-stationary sources that support a plan-
related facility and must be evaluated in connection with the air
quality component of the plan review. The specific requirements for
calculating attributed emissions are set out in proposed Sec.
550.205(d).
Given that BOEM is proposing to provide various alternative methods
to calculate attributed emissions, it may be possible these
alternatives could yield slightly different overall results and the
option chosen may not result in the highest potential calculation of
attributed emissions that might be derived. Providing for these
alternative methods reflects the reality that all relevant or necessary
data may not be available to a lessee or operator at the time its plan
is prepared and submitted to BOEM. Regardless of the ultimate method
used to allocate MSC emissions and derive attributed emissions,
however, no lessee or operator will be allowed to emit air pollutants
in an amount that exceeds what was approved in its plan and a lessee or
operator generating emissions in excess of its plan approval could be
subject to sanctions, including potential shut-in for a violation. In
addition, under this proposed rule, there are specific monitoring and
record-keeping provisions that would be added to ensure ongoing
compliance with the proposed regulations. For this reason, BOEM
anticipates that lessees or operators will be conservative in emissions
allocations.
Background Concentration
This new term would be defined to mean ``the ambient air
concentration of any given criteria air pollutant that arises both from
local natural processes and from the transport into the airshed of
natural or anthropogenic pollutants originating locally or from another
location, either as measured from an USEPA-approved air monitoring
system or as determined on some other appropriate scientifically
justified basis, as approved by BOEM.'' The background concentration of
a pollutant represents the concentration of any given pollutant that is
present prior to the establishment of operations related to a proposed
facility.
Evaluating compliance with the NAAQS requires the consideration of
two factors, (1) the background concentration of any given pollutant at
the point of measurement, and (2) the contribution to the concentration
that would be generated as a result of the facility being proposed. The
incremental amount of the pollutant that is contributed by the
operations associated with a plan is added to the background
concentration of that pollutant in order to determine the amount of
pollution that would exist as a result of the implementation of the
proposed plan. The sum of the background concentration for any given
pollutant and the incremental amount of the pollutant resulting from
the implementation of the proposed plan is referred to as the design
concentration of that pollutant. That design concentration represents
the value that is compared to the NAAQS in order to determine whether
or not the plan, if implemented as proposed, would cause an exceedance.
Baseline Concentration
The term baseline concentration would be defined as the ambient
background concentration of any given air pollutant which exists or
existed at the time of the first application for a USEPA PSD permit in
an area subject to sec. 169 of the CAA, based on air quality data
available to the USEPA or a State air pollution control agency and on
the monitoring data provided in the permit application. The proposed
definition would also state that the baseline concentration is
distinguished from the background concentration in that the background
concentration changes continually over time to reflect the current
ambient air concentration for any given air pollutant, whereas the
baseline concentration remains fixed until such time as a new AAI is
established for an attainment area. The difference between the current
background concentration and the baseline concentration represents the
change in actual concentration of a given pollutant in a relevant area
caused by natural and/or anthropogenic (i.e., other stationary and non-
stationary) sources that began operations after the date the baseline
concentration was established.
Best Available Control Technology (BACT)
This term would be revised from the definition that exists in the
current regulation. The proposed rule would define BACT to mean ``a
physical or mechanical system or device that reduces emissions of air
pollutants subject to regulation to the maximum extent practicable,
taking into account (1) the amount of emissions reductions necessary to
meet specific regulatory provisions; (2) energy, environmental, and
economic impacts; and (3) costs.'' This proposed definition and usage
of the term would differ from that of the USEPA, because the USEPA's
use of BACT refers to changes made in connection with the USEPA's
permit process under the CAA, and BOEM does not issue air quality
permits, nor does it make determinations of BACT pursuant to the CAA.
Rather, BOEM requires (and is proposing to continue requiring) BACT in
its review and approval of plans for which modeling has demonstrated
that projected emissions may cause or contribute to an exceedance of an
applicable AAQSB or a violation of the NAAQS.
In addition, BOEM and the USEPA differ in their requirements for
BACT, primarily due to the difference in their respective regulatory
frameworks. BOEM reviews the BACT alternatives as part of its AQRP,
under both the current regulation and the proposed rule prospectively,
determining in advance of the facility installation what form of BACT
is appropriate. The USEPA also evaluates BACT prospectively, but the
CAA also specifies, among other requirements, that BACT cannot be less
stringent than any applicable standard

[[Page 19764]]

of performance under the New Source Performance Standards (NSPS) (42
U.S.C. 7479(3)). Therefore, although BOEM looks to USEPA practices when
evaluating control technologies, due to the unique nature of the OCS,
BOEM also exercises independent judgment on what constitutes BACT and
how it should be applied. This definition also clarifies that BACT, as
used in this rule, is intended to refer to physical or mechanical
controls (i.e., changes to the equipment and technology), in contrast
to operational controls that would primarily involve changes in the
ways that equipment is operated (rather than changes to the equipment
itself).
With reference to ``the maximum extent practicable,'' under certain
circumstances, VOCs must be fully reduced to a rate at or below the
EETs (including through the use of BACT) whether or not such a
reduction would be considered practicable, unless emissions credits can
be applied (see Sec. 550.303(f)). In other words, under some
circumstances a plan could not be approved because the level of VOC
emissions would be too high, regardless of whether some ``practical''
method were available and if available was proposed to be applied to
mitigate or reduce the emissions. In that rare instance, the only
acceptable means to obtain approval of the plan would be for the lessee
or operator to obtain emissions credits to offset the effects of the
excessive VOC emissions.
Class I Area
The current regulations use this term but do not define it. Because
it is used more broadly in the proposed rule, BOEM proposes to define
it in the regulations. The proposed rule would define this term to mean
``an area designated by the USEPA, a State, or a Federally-recognized
Indian tribe, where visibility and air emissions are protected by a
Federal Land Manager, and protected to standards more stringent than
the NAAQS pursuant to 42 U.S.C. 7472(a) or 7474, as amended; \76\ Class
I areas include international parks and certain national parks,
wilderness areas, national monuments, and areas of special national or
regional natural, recreational, scenic, or historic value.'' Congress
has established a program to designate specific areas of the country as
Class I areas, and the USEPA defines these areas in its regulations at
40 CFR part 81 subpart D. Several tribes have also requested USEPA to
redesignate their lands from Class II to Class I to provide additional
air quality protection.\77\
---------------------------------------------------------------------------

\76\ The USEPA's guidance to tribes on Class I re-designations
is available here: https://www3.epa.gov/air/tribal/pdfs/GuidanceTribesClassIRedesignationCAA.pdf.
\77\ For example, the Northern Cheyenne Reservation, the
Flathead Indian Reservation, the Fort Peck Indian Reservation, the
Spokane Indian Reservation and the Forest County Potawatomi
Community Reservation. See 40 CFR 52.1382(c), 52.2497(c) and
52.2581(f).
---------------------------------------------------------------------------

Class II Area
Like the term ``Class I area,'' the current regulations use ``Class
II areas'' but do not define the term. The proposed rule would define
Class II area to mean ``an attainment area designated by the USEPA, a
State, or a Federally-recognized Indian tribe, that is protected less
stringently than a Class I area.'' A Sensitive Class II area
classification indicates a place the Clean Air Act would allow a
moderate change in the air quality, but where stringent air quality
constraints are nevertheless desired. This classification is less
stringent than for a Class I area, which describes a place where
minimal air quality degradation would be allowed, and more stringent
than that of a Class III area, which indicates a place where
substantial industrial or other growth would be allowed. Sensitive
Class II areas (see definition of this term, below) represent a subset
or sub-classification of Class II areas that are defined by federal
land management agencies as federal lands where the protection of air
resources has been prioritized, as specified in acts, regulations,
planning documents, or by policy.
Complex Total Emissions
The proposed rule would define this new term to mean ``the sum of
the facility emissions that would result from all of the facilities
that have been aggregated for the purposes of evaluating their
potential consolidated impact on air quality, pursuant to the
methodology set forth in Sec. 550.303(d), and the sum of all
corresponding attributed emissions for those facilities.'' For the
purposes of calculating complex total emissions, such emissions could
include the emissions from pipeline vessels, bury barges, and lay
barges during those periods of time while they are temporarily
connected to the seabed on the OCS as long as these vessels meet the
other requirements for complex total emissions consolidation. The
proposed requirement to consolidate air emissions from multiple
facilities in certain circumstances is described in more detail at the
discussion of proposed Sec. 550.303(d).
Criteria Air Pollutant or Criteria Pollutant
Criteria air pollutants are those pollutants for which the USEPA
sets NAAQS. The proposed rule would add this new term (also referred to
as criteria pollutant) (CP) to the proposed definitions section and
would be defined to mean ``any one of the principal pollutants for
which the USEPA has established and maintains a NAAQS under 40 CFR part
50 and in accordance with 42 U.S.C. 7409, as amended, for the
protection of public health and welfare.'' The proposed rule clarifies
that the USEPA has established primary standards for the protection of
public health, including sensitive populations, and it has established
secondary standards for the protection of public welfare from adverse
effect, including those related to effects on vegetation, ecosystems,
and visibility. The proposed rule would clarify criteria air pollutants
do not include VOCs or any other precursor air pollutant not already
regulated under the NAAQS. Precursor pollutants are defined under the
definition of precursor air pollutant or precursor pollutant as
explained later in this rulemaking.
The proposed rule would define CP so it has the identical meaning
as used by the USEPA. In those situations where BOEM intends for the
proposed rule to refer only to CPs rather than all air pollutants, it
has drafted the proposed rule so it specifically uses the term
``criteria pollutant.''
Design Concentration
The proposed rule would define design concentration to mean ``the
pollutant concentration at a given location projected, through
computer-simulated air dispersion or photochemical modeling, as
described under 40 CFR part 51, appendix W, section 7.2.1.1 to result
from your projected emissions, combined with the background
concentration for the same pollutant, averaging time, and statistical
form at the most appropriate receptor location.'' Each NAAQS has both
an averaging time and a statistical form. The statistical form tells
how the concentration level would be violated. For instance, the
``statistical form'' of the annual NO2 NAAQS is the annual
mean measured over three years.
The design concentration of any given CP is compared against the
NAAQS in order to determine whether or not the activities in a proposed
plan, together with the background concentrations, would exceed any
NAAQS at any point landward of the SSB. The appropriate background
concentration is measured

[[Page 19765]]

from the nearest point at which there is data from an USEPA-approved
air monitoring system, or as determined on some other appropriate
scientifically justified basis approved by BOEM. The design
concentration of any given CP is compared against the NAAQS in order to
determine whether or not the activities in a proposed plan would cause
the concentration of that pollutant at any point landward of the SSB to
exceed the level of the NAAQS. This approach takes into consideration
the pre-existing ambient air concentration of that criteria air
pollutant (i.e., the background concentration), as well as the
increment added as a result of the emissions generated by operations
associated with the proposed plan, in determining what the impact of
the plan's emissions will likely be at any given location.
Dispersion Modeling
This new term would be defined to mean ``the mathematical computer
simulation of air emissions being transported from a source through the
atmosphere under given meteorological conditions. Emissions from
sources, expressed as the rate of air pollutants emitted over time
(i.e., pounds per hour), are translated through computer modeling into
pollutant concentrations, expressed in units of micrograms of
pollutants per cubic meter of ambient air ([micro]g/m\3\), or in parts
per million or billion, depending on the circumstances.''
The dispersion model must take various factors into account,
including the amount of air emissions generated by the proposed
facility and the relevant meteorological conditions that would apply at
the proposed facility site, the nearby coast, and over submerged State
lands. The proposed rule would clarify that when a file containing
meteorological and emissions data are evaluated, the computer model is
used to project the concentrations of the pollutants at a receptor
location.
Under the proposed subpart C of this part (``Air Quality Analysis,
Control, and Compliance''), in the event that proposed operations
exceed EETs, results of dispersion and photochemical modeling would be
used to project the potential for a source to have a significant
adverse effect on the air quality of a State onshore or at the SSB, and
to discern whether the control of an individual emission source would
have the desired effect of reducing the emissions' impact for
compliance with the AAQSB.
Emission Control Efficiency (ECE)
This new term would be defined to mean the effectiveness of ERM for
any given emissions source and air pollutant. The greater the emission
control efficiency (ECE), the greater the relative effectiveness of the
underlying controls. ECE measures effectiveness on a relative basis
(i.e., as a percent of the pollution being reduced), rather than in
absolute terms (i.e., the total reduction in the annual tonnage of the
pollutant emitted). ECE varies from 100%, representing a control that
completely eliminates emissions, to zero, representing a control that
has no effect on such emissions. The proposed rule would describe the
requirements relating to ECE at proposed Sec. 550.309.
Emissions Credits
The proposed rule would supplement the use of the term ``emissions
offsets'' with the broader term ``emissions credits.'' Emissions
credits include emissions offsets as a subset. Emissions credits
represent emissions reductions from emission sources that have nothing
to do with the proposed plan or any facility or MSC associated with the
plan.
The definition of this term would be revised to mean ``emissions
reductions from an emissions source(s) not associated with the plan
that are intended to compensate for the excessive emissions of criteria
or precursor air pollutants, regardless of whether these emissions
credits are acquired from an emissions source(s) located either
offshore or onshore, including: (1) Emissions offsets generated by the
lessee or operator directly; or (2) emissions offsets acquired from a
third party; or (3) trading allowances or other alternative emission
reduction method(s) or system(s) associated with a market-based trading
mechanism, such as a mitigation bank, or through other market oriented
or competitive markets where these assets are exchanged.'' Emissions
credits are intended to compensate for excessive emissions associated
with any given plan. The new term ``emissions credits'' is intended to
have broader application than the existing defined term ``emissions
offsets.'' The proposed definition is intended to account for any
reduction in emissions from an emission source not associated with the
plan, whereas the existing definition only includes reductions from
facilities. The proposed defined term is used in subpart C to reflect a
proposed change whereby an emissions reductions of an equivalent amount
would be allowed in lieu of BACT or other emissions reductions
measures, regardless of whether such reductions are achieved on sources
owned by the lessee or operator or a third-party or regardless of
whether the reduction is obtained through the use of a market-based
trading mechanism, such as a mitigation bank. USEPA operates a number
of multi-State market-based emissions trading programs. Because these
programs have broad geographic coverage, purchase of allowances from
one of these programs would not be certain to reduce emissions from
sources in any particular AQCR. The intent of the proposed requirement
is that the purchase of emissions credits result in actual emissions
reductions in the affected State. Consequently, such multi-State
trading programs might not be an appropriate source of emission credits
under the proposed rule.
Emission Exemption Thresholds (EET)
The proposed rule would define this term to mean ``the maximum
allowable rate of projected emissions, calculated for each air
pollutant, expressed as short tons per year, above which facilities
would be subject to the requirement to perform modeling.'' The emission
exemption threshold formulas are in proposed Sec. 550.303.
Emissions Factor(s)
The proposed rule would define this term to mean a value that
relates the quantity of a specific air pollutant released into the
atmosphere with the operation of a particular emissions source. The
proposed rule would clarify emissions factors are usually expressed as
the mass of pollutant generated from each unit (e.g., mass, volume,
distance, work, or duration) of activity by the emissions source
emitting the pollutant.
Emission Reduction Measure(s) (ERM)
The proposed rule would define emission reduction measure(s) (ERM)
to mean any emissions credit(s), operational control(s), equipment
replacement(s), or BACT, applied on either a temporary or permanent
basis, to reduce the amount of criteria or precursor air pollutant
emissions that would occur in the absence of the application of such
measures.
Existing Facility
The current regulations define this term as ``an OCS facility
described in an Exploration Plan or a Development and Production Plan
submitted or approved before June 2, 1980.'' The proposed rule would
define this term to mean ``an operational OCS facility described in an
approved plan.'' The existing definition is much narrower than the
proposed

[[Page 19766]]

one, because the existing definition is both limited to facilities
described in EPs and DPPs (i.e., excluding DOCDs) and to those
facilities described in plans submitted prior to June 2, 1980.
Facility
The proposed rule would revise the definition that exists in the
current regulation. The proposed rule would define the term
``facility'' used in proposed Sec. 550.205 and proposed subpart C to
mean ``any installation, structure, vessel, vehicle, equipment, or
device that is temporarily or permanently attached to the seabed of the
OCS, including but not limited to a dynamically positioned ship,
gravity-based structure, manmade island, or bottom-sitting structure,
whether used for the exploration, development, production, or
transportation of oil, gas, or sulphur.'' The proposed rule would
specify all installations, structures, vessels, vehicles, equipment, or
devices directly associated with the construction, installation, and
implementation of a facility would be considered part of a facility
while located at the same site, attached, or interconnected by one or
more bridges or walkways, or while dependent on, or affecting the
processes of, the facility, including any ROV while attached to the
facility. The proposed rule would also specify that one facility may
include multiple drill rigs, drilling units, vessels, platforms,
installations, devices, and pieces of equipment. Also, under the
proposed rule, MODUs, even while operating in the ``tender assist''
mode (i.e., with skid-off drilling units), and any other vessel engaged
in drilling or downhole operations, including well-stimulation vessels
would be treated as facilities for purposes of evaluating air
emissions. Under the proposed rule, the term would also include all
Floating Production Systems (FPSs), including Column-Stabilized-Units
(CSUs), Floating Production, Storage and Offloading facilities (FPSOs),
Tension-Leg Platforms (TLPs), and spars. The proposed rule would also
provide any vessel used to transfer production from an offshore
facility be considered part of the facility while physically attached
to it. Finally, the proposed rule would specify all DOI-regulated
pipelines be considered facilities, as would be any installation,
structure, vessel, equipment, or device connected to such a pipeline,
whether temporarily or permanently, while so connected. The proposed
rule would therefore require both lease-term pipeline installations and
right-of-way pipeline installations to comply with BOEM's air quality
regulations.
The current regulation defines facility, as used in subpart C, as:
``[A]ny installation or device permanently or temporarily attached to
the seabed which is used for exploration, development, and production
activities for oil, gas, or sulphur and which emits or has the
potential to emit any air pollutant from one or more sources. All
equipment directly associated with the installation or device shall be
considered part of a single facility if the equipment is dependent on,
or affects the processes of, the installation or device. During
production, multiple installations or devices will be considered to be
a single facility if the installations or devices are directly related
to the production of oil, gas, or sulphur at a single site. Any vessel
used to transfer production from an offshore facility shall be
considered part of the facility while physically attached to it.''
The proposed definition would be similar to the current definition
in at least two ways. First, an onshore facility or onshore support
facility would not constitute a ``facility'' under the proposed
definition. Second, under the proposed rule one facility might include
multiple drill rigs, drilling units, vessels, platforms, installations,
devices, and pieces of equipment.
The proposed rule would generally reorganize the substance of the
current definition and provide examples and more explanatory text. In
addition, there are several notable substantive changes proposed.
First, the proposed rule would revise the definition by eliminating the
requirement that a facility ``emit or have the potential to emit any
air pollutant from one or more sources.'' This limitation could have
been read to imply that, for example, since sub-sea tiebacks and other
subsea devices do not themselves emit air pollutants, vessels engaged
in installing them were not facilities even though they were connected
to the seabed of the OCS. Removing this limitation would make clear
that any vessel which is temporarily or permanently attached to the
seabed such as a well-stimulation vessel or a pipeline laying vessel
connected via a subsea tieback, would be considered a facility for the
purposes of evaluating air emissions. Such a vessel would be considered
an MSC when not attached to the seabed. The current definition was
developed when wells were drilled individually and generally connected
separately to distinct production platforms. Now, many wells can be
drilled and connected to a single production facility from significant
distances, because subsea tiebacks are becoming increasingly viable,
both technically and economically. Similarly, under the proposed rule,
the same principle would apply to any structure or vessel that is
connected to a pipeline or which is laying a pipeline.
Second, whereas the existing definition specifies facilities are
``used for exploration, development, and production activities,'' the
proposed rule would add ``transportation'' to this list. This change is
intended to make the definition track the language in OCSLA Section
4(a), which includes installations and devices used for the purposes of
transporting oil and gas. This change would also reflect the fact the
definition now explicitly covers pipelines, which, though they do not
themselves normally emit air pollutants, are the means by which vessels
that do emit air pollutants are connected to the OCS.
The third change would specify more clearly any equipment directly
associated with a facility is considered part of that facility if it is
dependent on, or affects the processes of, that facility. The existing
definition contains the provision: ``During production, multiple
installations or devices will be considered to be a single facility if
the installations or devices are directly related to the production of
oil, gas, or sulphur at a single site.'' The proposed definition would
remove the references to production. Instead it would provide: ``All
installations, structures, vessels, vehicles, equipment or devices
directly associated with the construction, installation, and
implementation of a facility are part of a facility while located at
the same site, attached, or interconnected by one or more bridges or
walkways, or while dependent on, or affecting the processes of, the
facility.'' As a consequence of these changes, mobile sources of
emissions would generally be considered part of the facility only while
attached to a facility, and not part of the facility otherwise.
However, while these mobile sources, such as ice breakers and other
support vessels, would not usually be considered part of a facility,
and therefore not regulated by BOEM as a facility, their emissions
would be accounted for and reported as attributed emissions and would
be evaluated to determine whether a proposed plan would cause a
potential impact to a State's air quality and could, therefore, trigger
a requirement to apply controls in accordance with the requirements of
subparts B and C of this part.
Facility Emissions
The proposed rule would define this new term to mean, ``for any
given criteria or precursor air pollutant, the

[[Page 19767]]

annual rate, the maximum 12 consecutive month rolling sum, and the peak
hourly emissions from all emissions sources on or connected to a
facility'' (to be consistent with the State permit applications and
consistent with the standards for hourly NAAQS, as set by the USEPA).
Emissions data required to evaluate compliance with other NAAQS with
averaging periods between 1 year and 1 hour, such as the 24-hour
PM10 and PM2.5 NAAQS and the and rolling 3-month
Pb NAAQS would be estimated by applying temporal allocation factors to
annual emissions modeling, rather than by requiring facilities to also
provide emissions information for each of these averaging periods. As
described in proposed Sec. 550.205, under the proposed rule, facility
emissions along with attributed emissions would constitute projected
emissions.
Fugitive Emissions
The proposed rule would define this new term to mean the emissions
of an air pollutant from an emissions source that do not pass through a
stack, chimney, vent, or other functionally equivalent opening.
Fully Reduce(d)
The proposed rule would define this term to mean ``to decrease
emissions of VOCs to a rate that will not exceed the emission exemption
threshold calculated under subpart C Sec. 550.303(c), or to decrease
emissions of criteria air pollutants to a rate that will cause ambient
impacts that do not exceed the Significant Impact Levels set out in the
table in 40 CFR 51.165(b)(2), as amended.''
Long-Term Facility
The proposed rule would define this term to mean a facility that
remains at the same general location for three years or longer. Under
the current regulations, there is a definition for temporary facility,
but no corresponding one for long-term facility. Thus, although the
definition is new, the concept underlying the use of this term has been
in existence for many years.
There are two notable aspects of the proposed definition. First,
the definition would specify a facility located on the same lease block
or within one nautical mile of its original location is still
considered to be in the same location for purposes of the air quality
evaluation. Second, once a facility becomes attached to the sea floor
and is used for drilling, production, or transportation, it would be
considered to be ``in use.'' The fact it might not be used for the
entire year does not mean BOEM should not consider it to be located at
a site for the year. For example, under the proposed rule, a facility
that is located at a site for three months, then removed and later put
back into service at the same location the next year would be
considered in use at that location for two years. Likewise, under the
proposed rule, a facility that drills on the same block for three
months in each of ten years would be considered a long term facility
because it is operating at the same location for more than three years;
it would not be a short term facility by virtue of the fact it is only
physically located in the block for a total of thirty non-contiguous
months.
If a facility must move from the location where it first attached
to the seabed due to adverse weather or other conditions over which the
lessee or operator had no control, the proposed Sec. 550.313(b) would
allow the Regional Director to extend the time for which a facility
could avoid being classified as a long-term facility by the number of
months during which a lessee or operator is unable to operate at that
location.
Major Precursor Pollutant
The proposed rule would define this new term to mean any precursor
pollutant for which the States are required to report actual emissions
to the USEPA, as defined in 40 CFR 51.15(a).
MARPOL-Certified Engine \78\
---------------------------------------------------------------------------

\78\ Note that the USEPA requires that each MARPOL engine
installed on a U.S. vessel that operates internationally must have a
USEPA-issued Engine International Air Pollution Prevention (EIAPP)
certificate as well as the relevant Certificate of Compliance to the
applicable CAA standards also issued by the USEPA.
---------------------------------------------------------------------------

The proposed rule would define this new term to mean ``either: (1)
An engine with a power output of more than 5,000 kW and a per cylinder
displacement at or above 90 liters installed on a ship constructed on
or after 1 January 1990 but prior to 1 January 2000 that is subject to
Regulation 13.7 of MARPOL Annex VI; or, (2) an engine with a power
output of more than 130 kW built on or after January 1, 2000 that is
subject to Regulations 13.1 through 13.6 of MARPOL Annex VI.
According to USEPA, a MARPOL engine operated aboard a U.S. vessel
must have a U.S.-issued Enhanced International Air Pollution Prevention
for each engine, as well as the relevant Certificate of Compliance from
the USEPA.
Maximum Rated Capacity
The proposed rule would define this new term to mean ``the maximum
power an engine is capable of generating, expressed in kW, and if
necessary, as converted from mechanical horsepower (hpm, where 1 hpm of
power equals 745.699872 W or 0.745699872 kW) or from the International
Table values of British thermal units (BtuIT, where 1 BtuIT/hour of
power equals 0.29307107 Watts or 0.00029307107 kW).''
For the purposes of determining whether a proposed facility should
be exempt from modeling, the current regulation requires the reporting
of projected emissions based on ``the maximum rated capacity of the
equipment on the proposed drilling unit under its physical and
operational design'' 30 CFR 550.218(a)(3). Under the proposed rule,
this requirement would apply to all engines, not just the drilling
unit, because the emission inventory will also include attributed
emissions sources (Sec. 550.205(c) and (d)). The proposed rule, at
Sec. 550.205(d)(2)(ii), is aimed at estimating maximum emissions that
could occur given the engines that will be used, under any operating
constraint proposed by the source. This will involve determining the
type of engine operation that produces the highest emissions per hour
of operation, which for some pollutants will not be operation at
maximum rated capacity. However, even in such a case, information on
the maximum rated capacity will be useful for converting ``percent of
rated capacity'' into actual engine loads and therefore emissions, and
for generally documenting the types and sizes of engines that will be
operating as part of the planned activities.
The proposed definition of maximum rated capacity would specify
that that maximum rated capacity must be expressed in kW, or converted
from hpm, or British thermal units per hour from the International
Tables (BtuIT), since that is the most standard measure for power. In
contrast, the term horsepower (hp) has many values, including
mechanical hp, electric hp, international hp, metric hp, boiler hp, or
water hp. Because there is no standard unit for hp--the range of
equivalency is 735.5 watts to 750 watts; BOEM is proposing to use kW
instead.
Using kW would facilitate converting measurements and would ensure
the use of one consistent standard, International System of Units (SI),
in kilowatts. Also, using kW would eliminate the reporting or
misreporting of hp based on the many types of hp that can be used for
various purposes

[[Page 19768]]

and, thereby, improve the accuracy of the reports and information
submitted to BOEM.\79\
---------------------------------------------------------------------------

\79\ Units called ``horsepower'' (hp) have differing
definitions: There is mechanical hp, also known as imperial hp, of
exactly 550 foot-pounds per second (approximately equivalent to
745.7 watts); metric hp of 75 kg-m per second (approximately
equivalent to 735.5 watts or 98.6% of an imperial mechanical hp);
boiler hp used for rating steam boilers (equivalent to 34.5 pounds
(about 15.6 kg) of water evaporated per hour at 212 degrees
Fahrenheit (100 degrees Celsius), or 9809.5 watts); electric motor
hp (equal to 746 watts); and British Royal Automobile Club (RAC) hp
is one of the tax hp systems adopted around Europe which make an
estimate based on several engine dimensions (using a conversion rate
of 0.735 kW for 1 hp).
---------------------------------------------------------------------------

National Ambient Air Quality Standards (NAAQS)
The proposed rule would define this term to mean ``the ambient air
standards established by the USEPA, as mandated by the CAA (42 U.S.C.
7409), set out in 40 CFR part 50, for the criteria air pollutants
considered harmful to public health or welfare when concentrations are
elevated over time.'' The proposed definition would explain that the
NAAQS consist of two categories, both of which are included within the
defined term: Primary standards that set limits to protect public
health, including the health of ``sensitive'' populations such as
asthmatics, children, and the elderly; and secondary standards that set
limits to protect public welfare, including protection against
visibility impairment, prevention of harm to animals, including marine
mammals, fish and other wildlife, and avoidance of damage to crops,
vegetation, and buildings.
Non-Attainment Area
The proposed rule would revise the definition that exists in the
current regulation to mean, for any given criteria air pollutant, a
geographic area, which the Administrator of the USEPA has determined
exceeds a primary or secondary NAAQS, as codified at 40 CFR part 81
subpart C. A designated ``non-attainment area'' is defined in the
current rule as, ``for any given criteria air pollutant, an area which
is shown by monitored data or which is calculated by air quality
modeling (or other methods determined by the Administrator of [US]EPA
to be reliable) to exceed any primary or secondary ambient air quality
standard established by [US]EPA.'' This revision is necessary because
the existing definition does not clarify that any given area may be
designated as an attainment area for one criteria air pollutant and yet
be a designated non-attainment area for another criteria air pollutant.
Operational Control(s)
The proposed rule would define this term to mean a process, method,
or technique, other than a physical or mechanical control or equipment
replacement, that reduces the emissions of criteria or precursor
pollutants (e.g., limitation on period of operation, load balancing,
use of less-polluting fuels, and/or operating equipment at less than
full capacity). Operational control(s) would include, but not be
limited to, operating a vessel or facility for a limited number of
hours per day, limiting the total amount or type of fuel used over a
period of time, load balancing or operating equipment at some level
less than full capacity.
Particulate Matter (PM)
The proposed rule would define this new term to mean ``an airborne
contaminant consisting of particulate matter that is regulated as a
criteria air pollutant under the ambient air standards.'' The proposed
rule would explain that PM10 refers to airborne contaminants
of particulates less than or equal to 10 micrometers. PM10
is distinct from coarse PM in that coarse PM consists of particulate
matter equal to or less than 10 micrometers but greater than 2.5
micrometers. Further, it would explain PM2.5, or fine PM, is
an airborne contaminant of particulates less than or equal to a
diameter of 2.5 micrometers.
Plan
The proposed rule would add this term to the definitions section to
mean ``any initial, revised, modified, resubmitted, or supplemental
Exploration Plan (EP), or DPP, DOCD, or application for a Right-of-Use
and Easement (RUE), a Pipeline ROW, or lease term pipeline.'' The term
``plan'' is used throughout proposed Sec. 550.205 and proposed subpart
C, and this definition would make explicit it is intended to refer to
all plans, regardless of whether a plan is for exploration or
development or whether it is an initial plan or a revised, modified,
resubmitted, or supplemental plan. For simplicity, where the term plan
is used in proposed Sec. 550.205 or proposed subpart C, the specific
requirement would be equally applicable to all types of plans.
Potential To Emit
The definition of ``potential to emit'' is derived from the USEPA
regulations at 40 CFR 51.301. In this proposed rule, the term is used
in a manner similar to that of the term ``facility emissions.'' Both
terms are meant to describe the measure of the maximum potential rather
than the actual emissions of a stationary source. In this proposed
rule, the term facility emissions is generally used to refer to the
emissions of sources regulated under BOEM's AQRP, whereas PTE is used
to refer to the emissions of sources not regulated by BOEM.
Potential to emit means the maximum capacity of a source to emit a
pollutant under its physical and operational design. Any physical or
operational limitation on the capacity of the source to emit a
pollutant including air pollution control equipment and restrictions on
hours of operation or on the type or amount of material combusted,
stored, or processed, shall be treated as part of its design if the
limitation or the effect it would have on emissions is federally
enforceable. Attributed emissions \80\ do not count in determining the
PTE of a stationary source.
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\80\ The USEPA refers to attributed emissions as secondary
emissions, which it defines in 40 CFR 52.21.
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Precursor Air Pollutant or Precursor Pollutant
The proposed rule would add this new term to mean ``a compound that
chemically reacts with other atmospheric gases to form a criteria air
pollutant.'' The proposed definition notes some precursor air
pollutants are also defined as criteria air pollutants. The proposed
definition would also explain precursor air pollutants include VOCs,
NOX, SO2, and NH3.
Projected Emissions
The proposed rule would define this new term to mean ``for any
given criteria or precursor air pollutant, the sum of one facility's
emissions and its corresponding attributed emissions over the specified
time period, with the controlled or uncontrolled nature of the
pollutants specified by the context.'' Projected emissions include the
attributed emissions from offshore vessels and offshore vehicles that
support a facility. The individual pollutants included among the
projected emissions may be reported on an annual basis or as peak-hour
projected emissions, and may be either uncontrolled or controlled and
may or may not require the use of BACT, emissions credits, or other ERM
from any source(s) as described in Sec. 550.205(e) and (f).
Proximate Activities
The proposed rule would define this term to mean ``activities that
involve or affect any of the following: The same

[[Page 19769]]

well(s); a common oil, gas, or sulphur reservoir; the same or adjacent
lease block(s); or, facilities located within one nautical mile of one
another.'' The proposed definition would also specify that, where a
well is drilled from one facility, but production from the well will
ultimately take place through a different facility, the drilling and
production activities constitute proximate activities if they occur
within the same twelve-month period.
Sensitive Class II Area
The proposed rule would define this new term to mean ``a Class II
area defined by an FLM agency as being federal land where protection of
air resources has been prioritized, as specified in acts, regulations,
planning documents, or policy.'' Agencies with land management
responsibility commonly refer to federal land areas that are not Class
I areas but are environmentally sensitive as sensitive class II areas.
Although the USEPA has not defined different air quality standards or
benchmarks for sensitive Class II areas, Federal Land Managers give
special attention and subject sensitive Class II area to a more
extensive air quality review than would normally be accorded to a
typical Class II area. In the context of this rule, an important
example of a sensitive Class II area would be the Arctic National
Wildlife Refuge in Alaska.
Short-Term Facility
This new proposed term would replace the term ``temporary
facility'' in current Sec. 550.302. The proposed rule would use this
new term with a similar but expanded meaning. The proposed definition
has been expanded so now any facility that is not a long-term facility
or is not connected to such a facility would be considered a short-term
facility.
If a facility must move from the location where it first attached
to the seabed due to adverse weather or other conditions over which the
lessee or operator had no control, the proposed Sec. 550.313 would
allow the Regional Director to extend the time for which a facility
could be classified as a short-term facility by the number of months
during which a lessee or operator is unable to operate at that
location.
BOEM recognizes that the USEPA classifies a short-term facility as
being a facility that is located at the same location for no more than
two years and solicits comments on the implications of retaining or
potentially changing this longstanding practice.
Significant Impact Level (SIL), or Significance Level
The proposed rule would define these terms to mean ``an ambient air
benchmark that applies to the ambient air impact of the emissions of a
criteria air pollutant, as set out in the table in 40 CFR.
51.165(b)(2).'' The terms ``significant impact level'' and
``significance level'' mean the same thing and are interchangeable.
Technically Feasible
The proposed rule would define this new term to mean ``a technology
or methodology that: (1) Has been demonstrated and operated
successfully on the same type of emissions source as the one under
review; or (2) is available and applicable to the type of emissions
source under review.''
BOEM solicits comments on whether the technical feasibility should
have to be demonstrated for the particular source identified in the
plan or whether the feasibility could be demonstrated through use of
similar but different sources.
Total Support Emissions
The proposed rule would define this new term to mean ``for any
criteria or precursor air pollutant, the total emissions generated by
an MSC that operates in support of your and any other facilities, for
the 12-month period over which the corresponding facility emissions are
measured.'' Proposed Sec. 550.205(d) would set forth an example for
calculating total support emissions.
Section 550.303--What analysis of my projected emissions is required
under this subpart?
Section 550.303(a)--Establishing Emission Exemption Thresholds
BOEM establishes emission exemption thresholds (EETs). BOEM would
define EETs as the maximum allowable rate of projected emissions,
calculated for each air pollutant, above which facilities would be
subject to the requirement to perform modeling. These EETs would
establish those levels of consolidated emissions below which BOEM has
determined would not cause or contribute to a violation of the NAAQS.
The proposed rule would provide that, if projected emissions or
complex total emissions are exempt, then the lessee or operator would
not be required to perform air quality modeling in accordance with the
requirements of proposed Sec. 550.304 of this subpart and to apply any
controls, as described in proposed Sec. Sec. 550.305 through 550.307.
Paragraph 550.303(b)--Calculating Projected Emissions
These paragraphs would establish the requirement that a lessee or
operator must compare its projected emissions or its complex total
emissions with the applicable EETs. More detailed requirements for
calculating and reporting projected emissions, facility emissions, and
attributed emissions are set forth in proposed Sec. 550.205 and
explained in the preamble discussion regarding that provision.
Paragraph 550.303(c)--Emission Exemption Threshold(s)
Under the proposed rule, BOEM would determine whether the lessee or
operator's projected emissions or complex total emissions have the
potential to significantly affect the air quality of any State, in
accordance with the EETs calculated under this proposed paragraph. This
paragraph would provide that BOEM will, sometime after the rule is
finalized, publish updated EETs in the Federal Register. These
thresholds would be based on criteria proposed in this rule and would
fall within a range proposed in this rule. Under the proposed rule,
until such time as BOEM has published these new EETs in the FR (herein
referred to as the date of the Notice) \81\ and has solicited public
comment thereon, a lessee or operator's projected emissions or complex
total emissions would be exempt if its projected emissions or complex
total emissions are below the EETs set in the current regulation at
Sec. 550.303(d). During this period, the distance variable in these
formulas would continue to be the shortest distance of the facility to
the shoreline, as is the case under the current rule. The proposed rule
would require BOEM to provide notice of proposed EETs in the FR, and an
opportunity to comment on them, any time it subsequently issues new
EETs or revises existing ones.
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\81\ Estimated to take place in 2020.
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The proposed rule would establish the process BOEM would follow to
provide notice of proposed EETs in the FR, and an opportunity to
comment on them, any time it subsequently issues new EETs or revises
existing ones. BOEM anticipates that it would establish new EETs based
on the EET studies currently underway and would publish these in the FR
after the completion of the studies (estimated in 2020). BOEM would
then require that all future plans be evaluated in terms of their
effects on the air quality of neighboring States by considering the
impacts landward of the SSB (including

[[Page 19770]]

the air above the State's submerged lands, at the shoreline and inland
of the shoreline). New EETs for those pollutants added to this proposed
rule will not be established until such time as the relevant studies
have been completed.
Section 550.303(c)(2) of the proposed rule provides criteria that
BOEM would use to determine the formulas that BOEM would publish in the
FR. These include: The absolute level of projected emissions; the
distance of the proposed facility or facilities from any State or from
critical natural resources, animals, and habitats; the existing ambient
air pollution in potentially affected States; the trend in the ambient
air pollution in those States; the associated attainment status of such
areas and the associated effects to public health and welfare; any
USEPA AAQSB applied by this proposed rule; the types, frequency and
duration of any air pollutant emissions and their formation and/or
dispersion characteristics; the characteristics of the facility or
facilities and MSCs, including the type and nature of the emissions
sources, and the height of the associated emission points or stacks;
the prevailing meteorological characteristics in any given area,
including air stability, relevant wind speeds and directions; the
amount of emissions from existing facilities and vessels in the
vicinity of the proposed facility; and other necessary and appropriate
conditions. Several of these criteria (used to determine the EETs) are
localized and may differ according to area even within one OCS region
(e.g., prevailing meteorological characteristics and the amount of
emissions from existing facilities and vessels in the vicinity).
Accordingly, BOEM expects that the EETs it would set in the FR would
vary from area to area. This could result in different sets of formulas
for each planning area or smaller geographic unit.
The proposed rule also would establish a range within which these
new EET formulas will apply. Above this range, lessees and operators
would always be required to perform air quality modeling, in accordance
with the requirements of Sec. 550.304 of this subpart, or to apply
controls, as described in Sec. Sec. 550.305 through 550.307, and below
this range lessees and operators would not be required to do so. Within
this range, lessees and operators would be exempt from these
requirements only if their projected or complex total emissions were
below the EETs defined by the formulas BOEM will publish in the FR.
Proposed Sec. 550.303(c)(3)(ii) would set the upper boundary of
this range. The proposed subparagraph would set the upper bounds of
this range with the current EET formulas (currently codified at 30 CFR
550.303(d)). However, the distance variable in the formulas would be
measured from the closest point on the SSB.\82\ Because this feature of
the upper boundary formulas would allow the upper boundary to vary all
the way down to zero (when the distance is zero), BOEM is proposing to
set constant values for the EETs for facilities within the first three
nautical miles of the State's seaward boundary. These proposed values
would be based on the current values of the current emission exemption
formulas at the SSB, and, for all pollutants other than CO, they would
correspond to the 100 tpy major source criteria from the USEPA NSR
permitting program, as defined in its regulations at 40 CFR part
70.\83\ Chart II, below, depicts how the current thresholds would shift
to become the upper boundaries of the range once BOEM publishes the
future thresholds in the Federal Register. The highest series
represents the current thresholds, while the two lower series represent
the EETs that would apply to those States with three and nine nautical
mile State submerged land boundaries, respectively.
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\82\ Because these same formulas would also serve as the EETs
during the period after the rule is finalized and before the new
formulas are established in the FR, subparagraph (4)(i) sets forth
the same formulas as (4)(ii) but defines the distance variable as
the distance from the shoreline.
\83\ The USEPA has two thresholds used to determine what
constitutes a major source for purposes of its permitting program.
In addition to the 28 source categories for which the 100 tpy
threshold applies, the USEPA has a 250 tpy threshold that applies to
other source categories. BOEM's existing exemption thresholds were
originally based on the 100 tpy standard and BOEM has elected to
retain this as the criteria, since it is a more conservative
approach.
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At the present time, BOEM does not have EETs for Pb,
PM2.5, or PM10, nor has it established EETs that
would apply to anything other than the projected annual emissions.
Until such time as EETs are established for these pollutants, no plan
would be required to model on the basis of their emissions of these
pollutants alone (except for Pb, for which the proposed rule would set
an EET which could trigger a requirement for modeling).
BOEM recognizes there may be a more appropriate distance-adjusted
maximum emission exemption threshold for these pollutants and solicits
comments from stakeholders on what they should be. Any comments should
include an analysis of the reasoning used to support an alternative
threshold, keeping in mind that the key goal is to ensure that offshore
projected emissions of Pb, PM2.5, or PM10 do not
``cause or contribute to a violation'' of their corresponding NAAQS.
Proposed Sec. 550.303(c)(3)(i) would set the lower boundary of
this range. The proposed formulas for these minimums represent
emissions levels below which the ambient air impact at the nearest
point in a State would not exceed any annual SIL. To derive these
equations BOEM used a Gaussian dispersion equation, setting the
concentration variable of the equation equal to a SIL and solving for
the corresponding emissions rate. An example of the theoretical model
underlying this analysis is provided for illustration purposes below:
\84\
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\84\ BOEM Alaska OCS Region, 2015, Chukchi Sea Planning Area Oil
and Gas Lease Sale 193 in the Chukchi Sea, Alaska Final Second
Supplemental Environmental Impact Statement BOEM 2014-669.

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[[Page 19771]]

[GRAPHIC] [TIFF OMITTED] TP05AP16.004

In deriving these equations BOEM used conservative assumptions
regarding the wind speed, stack height and air stability. For a full
description of the method used to derive these equations see the
Appendix: BOEM Analysis of Minimum Emission Exemption Thresholds
available in the rulemaking docket at www.regulations.gov.
If you have questions concerning the analysis done regarding the
formulas or analysis related to the minimum emission exemption
thresholds, you may contact Virginia Raps of the BOEM Alaska OCS
Regional Office, by mail at the Bureau of Ocean Energy Management,
Alaska OCS Region, 3801

[[Page 19772]]

Centerpoint Drive, Suite 500, Anchorage, AK 99503, or by email at
Virginia.Raps@boem.gov, or by phone at (907) 334-5200.
The following chart illustrates the proposed emission exemption
thresholds for NOX. It shows the current exemption
threshold, the proposed maximum exemption threshold, and the proposed
minimum exemption threshold for NOX. The chart shows that
the proposed maximum threshold would have the same slope as the current
threshold but would shift slightly lower due to proposed rule's
changing the ``distance'' variable to be measured from the SSB. The
space in-between the proposed maximum and the proposed minimum
represents the range where BOEM would apply the formulas it will
publish in the Federal Register.
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\85\ This chart would apply to all CPs other than CO, ozone and
lead.
[GRAPHIC] [TIFF OMITTED] TP05AP16.005

Section 550.303(c)(3)(i) lists the formulas for the proposed new
minimum emission exemption thresholds for those CPs for which the USEPA
has established SILs. Paragraph 303(c)(ii) would include a minimum
emission exemption threshold for Pb. To establish a minimum emissions
exemption level for Pb, the proposed rule would adopt the USEPA
significant emissions rate for Pb, as described in USEPA regulations at
40 CFR 52.21(b)(23)(i). This amount is currently set at 0.6 short tons
of emissions per year. BOEM is proposing this addition in order to
ensure consistency with USEPA regulations and to ensure all OCS
facilities comply with the requirements of OCSLA. BOEM is not proposing
to establish a distance-based formula for Pb because the USEPA has not
established SILs for Pb which would enable BOEM to apply the above
methodology. Instead, BOEM is proposing to utilize the USEPA's
significant emissions rate for Pb as an emissions threshold.
As an alternative to the proposed distance-based formula, BOEM is
also considering an option in which it would establish new minimum EETs
based on the PSD emissions limits in the USEPA's regulations at 40 CFR
52.21(b)(23)(i). Those USEPA tables are intended primarily to determine
whether a facility will generate potentially significant incremental
increases in pollutant concentrations in the area surrounding the
proposed

[[Page 19773]]

emissions source. BOEM could either apply the current absolute numbers
or utilize the values in the USEPA table and adjust them, on either a
linear basis or on the basis of a Gaussian dispersion equation, in an
appropriate manner based on the distance of the facility from the
State.
BOEM solicits comments on this and other possible alternative
approaches to establishing new maximum EETs (above which all plans
would be subject to modeling) and minimum EETs (below which BOEM would
not establish any new EETs).\86\ Such a discussion would ideally
include information both on the levels of the two sets of formulas, as
well as on the type and nature of the formulas that should be applied.
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\86\ With the adoption of the new EETs, there would be no need
for any lessee or operator to review or evaluate their emissions as
compared to the minimum thresholds because those minimums will, in
all cases, be below the EETs.
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Finally, because the NAAQS are subject to change as scientific
knowledge improves and because technical and modeling capabilities may
improve over time, the proposed rule provides that BOEM, at its
discretion, would revise the emission exemption thresholds on an
ongoing basis either as a result of a change in an applicable standard
or because BOEM's ability to measure and evaluate the impact of
existing emission exemption thresholds has improved or for some other
reason. Thus, under the proposed rule, if the USEPA revises the NAAQS,
or any applicable SIL or AAI, BOEM would examine the appropriateness of
its emission exemption thresholds, and, BOEM, at its discretion, could
periodically revise its exemption formula(s) or its exemption threshold
amount(s) for the corresponding air pollutant(s), as appropriate.
Paragraph 550.303(d)--Consolidation of Air Pollutant Emissions From
Multiple Facilities
The purpose of this section is to determine whether two or more
facilities wholly or partially owned, controlled or operated by the
same entity that are located in relatively close proximity may
collectively cause or contribute to a violation of any relevant air
quality standard or benchmark, even if they would not do so when
considered on a separate basis.
The proposed rule would require projected emissions from multiple
facilities under common ownership to be combined for analysis and
reported as complex total emissions under certain circumstances. BOEM's
current practice is to require, in specific circumstances, the
consolidated analysis of facilities covered by multiple plans in
accordance with the following provision of Sec. 550.303(j): ``If,
during the review of a new, modified, or revised Exploration Plan or
Development and Production Plan, the Regional Supervisor determines or
an affected State submits information to the Regional Supervisor which
demonstrates, in the judgment of the Regional Supervisor, that
projected emissions from an otherwise exempt facility will, either
individually or in combination with other facilities in the area,
significantly affect the air quality of an onshore area, then the
Regional Supervisor shall require the lessee to submit additional
information to determine whether emission control measures are
necessary.'' The current regulations do not specify under what
circumstances the Regional Supervisor would make such a determination.
This proposed paragraph recognizes the fact that emissions from two
or more OCS facilities located in close proximity to one another may
have an impact on the air quality of a State, when operated
contemporaneously, even in those situations where the emissions from
any one of those facilities, when compared against the emission
exemption thresholds, would indicate that that facility should not
cause an adverse impact to the air quality of a State. Closely-grouped
facilities that emit pollutants at the same time can affect the air
quality of a State differently than facilities that are spread across a
larger area. The proposed rule would require a lessee or operator to
add together its projected emissions with the emissions from other
facilities whether or not they are described in lessee or operator's
plan and whether they currently exist or are proposed.
The proposed paragraph would specify the conditions under which a
lessee or operator would be required to consolidate the projected
emissions from multiple facilities. Under the proposed rule, projected
emissions from multiple facilities would be required to be consolidated
if: (1) The emissions from multiple facilities are generated by
proximate activities (i.e., the same well(s); a common oil, gas, or
sulphur reservoir; the same or adjacent lease block(s); or, by
facilities located within one nautical mile of one another); (2) the
lessee or operator wholly or partially owns, controls or operates those
facilities; (3) the construction, installation, drilling, operation, or
decommissioning of any of the lessee or operator's facilities occurs
within the same 12-month period as the construction, installation,
operation, or decommissioning of another facility that meets conditions
1 and 2; and (4) such a consolidation of emissions from multiple
facilities would generate emissions sufficient to exceed an applicable
emission exemption threshold.
If any two or more facilities meet all of the conditions specified
in paragraphs (d)(1)(i) through (iv) of this proposed section the
lessee or operator would be required to calculate the sum of the
projected emissions from those facilities (including its respective
attributed emissions), as the complex total emissions for its plan.
If there are two or more facilities that would normally be
submitted in one plan, and which are intended to be part of one unit or
project, those facilities should be evaluated together. This
requirement is intended to discourage submission of multiple plans for
the purpose of remaining under the exemption thresholds. This
requirement would be applied only to facilities that are wholly or
partially owned, controlled or operated by the same party. This
limitation is intended to further ensure that the associated air
quality analysis would be applied consistently across projects,
regardless of whether a lessee's or operator's project is submitted for
approval in one plan or whether it submits several plans separately.
According to BOEM regulations (in Sec. 550.105), a lessee is
defined as being ``a person who has entered into a lease with the
United States to explore for, develop, and produce the leased minerals.
The term lessee also includes the BOEM-approved assignee of the lease,
and the BOEM-approved sublessee of operating rights in the lease.'' The
definition of ``you'' includes a ``lessee, the owner or holder of
operating rights, a designated operator or agent of the lessee(s), a
pipeline ROW holder, or a State lessee granted a right of use and
easement.'' Thus, the requirement for common ownership of a facility
would extend to the lessee or their assignee as well as to those that
share other lease interests, including joint ownership in a common
unit, joint operating rights interests, as well as companies that use
the same designated operator or unit operator for those facilities
located in the same general vicinity of the proposed new facility.
In order to determine common ownership, BOEM will rely on the
criteria defined by the Office of Natural Resources Revenue (ONRR) for
evaluating whether or not two companies should be considered
affiliates, as defined in the regulations at 30 CFR 1206.101 and 30 CFR
1206.151. BOEM solicits comments from lessees

[[Page 19774]]

and operators with respect to how it could most effectively limit the
application of these consolidation criteria to relevant parties and
avoid the consolidation of emissions associated with facilities that
are operated by unaffiliated companies.
Facilities whose projected emissions would have been consolidated
but for the exemption related to ownership and control would still be
evaluated for their consolidated effects to the States outside of the
AQRP. BOEM will conduct independent studies regarding the consolidated
effects of multiple facilities on the air quality of the neighboring
States and will also evaluate the potential for future cumulative
impacts in conjunction with the associated NEPA review of the Five-Year
Oil and Gas Leasing Program, the associated lease sales and the lease
sale EISs.
The proposed paragraph would also specify that if all of the
emissions to be combined relate to the lessee's or operator's wholly-
owned facilities, then the lessee or operator would be required to
provide the data and analysis regarding the complex total emissions.
However, where the lessee or operator does not fully own all of the
facilities whose projected emissions are to be consolidated, the lessee
or operator would need to gather data either from the operator of any
facilities that it does not wholly own or which it does not operate, or
from the publically available database of plans approved by BOEM, and
would need to provide all the data and analysis it gathered. BOEM would
make a determination whether the lessee or operator has appropriately
considered the relevant data in its analysis of the complex total
emissions. If all of the emissions to be combined relate to the lessee
or operator's wholly-owned facilities, that lessee or operator must
provide all the data and analysis of the complex total emissions.
Under the proposed rule, if any lessee or operator were required to
consolidate projected emissions data from multiple facilities, then
anywhere a proposed requirement is written to apply to projected
emissions that proposed requirement would instead apply to complex
total emissions, except with respect to the process by which projected
emissions are determined for any given facility (as specified in Sec.
550.205(c), (d), and (e)).
Paragraphs 550.303(e) and (f)--Emissions Do Not Exceed any Threshold or
Exceed a Threshold
The purpose of these two paragraphs is to determine whether the
facility or facilities covered by a proposed plan should be required to
do modeling to determine whether, or to what extent, its operations
might adversely affect the air quality of a State. If a plan is
proposed that would result in operations such that none of the EETs
would be exceeded, then the plan would not be required to include air
quality modeling. This is because BOEM would already have determined
that the potential effects resulting from the implementation of that
plan would not have the potential to cause any such adverse effect.
Under the proposed Sec. 550.303(e), if none of a plan's projected
emissions or complex total emissions for any precursor or CP that
exceeds the applicable emission exemption threshold, then its projected
emissions would be considered de minimis, and therefore exempt, so that
no further analysis would be required under subpart C.
Under the proposed Sec. 550.303(f), if a lessee's or operator's
projected emissions or complex total emissions of the precursor or
criteria air pollutant exceed the applicable emission exemption
threshold, then further review would be required and potentially also
controls. Under the proposed rule, the requirements associated with an
exceedance would depend on which pollutant or pollutants exceed the
threshold(s). If emissions of VOCs, which have no SILs, exceed a
threshold, then controls would be required pursuant to proposed Sec.
550.306 or 550.307, depending on whether the facility is short-term or
long-term. If emissions of a criteria air pollutant exceed a threshold,
then modeling would be required under proposed section 550.304. The
current rule accounts for both of these two scenarios, just as the
proposed rule would.
The proposed rule would add provisions specifying circumstances in
which additional photochemical modeling would be required. One of these
proposed provisions would require photochemical modeling of
O3 when projected emissions exceed the applicable emission
exemption threshold for the O3 precursors NOX,
VOCs, or CO. A second new proposed provision would require
photochemical modeling for PM2.5 if a plan's projected
emissions of the PM2.5 precursors, NOX, VOCs,
PM2.5, or SO2, exceed the applicable emission
exemption threshold. In both cases, the proposed rule would not impose
these photochemical modeling requirements, until such time as the
conditions specified in Sec. 550.304(b) have been met.
Paragraph 550.303(g)--Changes to Previously Approved Plans
The proposed rule would set requirements specifying when lessees
and operators must submit revisions to their plans based on changes to
how the plan will be implemented. The first proposed paragraph, (g)(1),
would provide that, if a lessee or operator changes its plan
implementation, such that its projected emissions would occur in years
other than those that were previously approved, it would be required to
submit a new plan and obtain approval before it implements the proposed
changes. This requirement would relate to when operations occur, not
the level of emissions associated with those operations.
This proposed provision would formalize an existing practice
whereby a lessee or operator is required to submit a new plan if the
actual emissions associated with its operations will likely occur in
years other than those proposed and approved in the original plan.
Depending on the timing of the prospective emissions, the air impacts
of those emissions would vary due to other activities in the area and
to seasonal effects. For future years, the NAAQS or air quality
benchmarks may change. In addition, the complex total emissions
analysis may need to be redone or reevaluated.
The second proposed paragraph, (g)(2), would provide that, if a
lessee or operator anticipates any increase in the maximum air
pollutant emissions above that projected for any time period described
in the previously approved plan, the lessee or operator would be
required to submit a new plan, pursuant to 30 CFR 550.283(a)(4). That
existing section provides that an operator must submit a revised plan
if it proposes to increase the emissions of an air pollutant to an
amount that exceeds the amount specified in the approved plan. The
proposed provision would relate to the peak emissions that would be
generated by the facility, including its attributed emissions, for any
time period (annual, 12-month rolling sum or maximum hourly) during its
OCS operations.
The third proposed paragraph, (g)(3), would provide that, if a
lessee or operator proposes to make a change to operations on its
existing facility or facilities, but not to the equipment used in such
operations, such that its approved projected annual emissions in any
given year are higher than those previously approved for the particular
year, but lower than the maximum air pollutant emissions for any year,
the lessee or operator would not need to

[[Page 19775]]

submit a revised plan--as long as the operations would occur in the
same year as described in the previous plan.
The fourth proposed paragraph, (g)(4), would require that a lessee
or operator submit a new plan any time it proposes to change any
equipment on its existing facility or facilities such that the proposed
change would result in an increase in air pollutant emissions from that
specific equipment for any air pollutant, regardless of the impact on
the total emissions of the facility as a whole.
The fifth proposed paragraph, (g)(5), would specify if a plan was
approved for a short-term facility and it was determined later that the
facility would be used in such a manner that it would properly be
classified as a long-term facility, then a new plan must be submitted
for review and approval by BOEM.
Paragraph 550.303(h)--Federal Land Manager
BOEM currently consults with appropriate FLMs when it has reason to
believe a lessee's or operator's proposed OCS activities could
potentially cause a significant effect on air quality in a Class I
area. Under the current practice, BOEM occasionally asks lessees and
operators to submit additional information to show their proposed
activities would not significantly affect the air quality of such
areas.
The proposed rule would expressly provide that BOEM may consult
with one or more relevant FLMs if it believes emissions from proposed
activities could potentially have a significant effect on Class I areas
or sensitive Class II areas onshore or above State submerged lands. It
would further provide that BOEM would consider the views of the FLMs in
determining whether the proposed plan complies with the provisions of
proposed subpart C. Based on this consultation, BOEM might require
additional information and analysis, either prior to or as a condition
of approving the plan. Finally, it would state that, if the FLM does
not raise any concerns regarding the plan in a timely manner, BOEM
would assume the FLM has no objections to the plan.
Under current practice and the proposed rule, the FLMs would
independently evaluate the potential impacts of air pollutant emissions
from OCS activities because of their expertise, modeling and evaluation
skills. They have the unique ability to evaluate and determine the
likely impacts of OCS activities on Class I and sensitive Class II
areas.
Section 550.304--What must I do if my projected emissions exceed an
emission exemption threshold?
Paragraph 550.304(a)--Dispersion Models
Paragraph 550.304(a) of the proposed rule describes BOEM's proposed
dispersion modeling requirements, which would apply in the event the
lessee or operator's projected emissions or complex total emission
exceed the limits defined in Sec. 550.303(c). Dispersion modeling
shows how a pollutant that is emitted could affect the concentrations
of that pollutant onshore or above State submerged lands. BOEM has
determined air pollutant emissions could potentially affect a State
only under those circumstances where the total annual projected
emissions or the complex total emissions of any given pollutant exceed
a relevant exemption threshold. For this reason, a lessee or operator
must perform modeling to estimate the projected increase in the ambient
concentration of a pollutant onshore only if its proposed plan proposes
projected emissions that exceed an emission exemption threshold for one
or more criteria air pollutants.
The proposed rule would clarify that if a lessee or operator's
projected emissions, or complex total emissions, of any given criteria
or precursor pollutant exceeds an emission exemption threshold, then
the lessee or operator would be required to model the potential impact
of those emissions and those of any other pollutant for which the
exceeding pollutant is a precursor, in order to determine the potential
impact to the State. However, the rule would not require that a lessee
or operator perform modeling with respect to those pollutants whose
emissions are not projected to exceed any relevant EET. This approach
is similar to that taken by the USEPA and is done for the same reason,
namely to ensure that emissions are modeled in situations where a
potential impact may occur. The USEPA method relies on the use of its
SERs to make this determination, rather than requiring modeling,
however.\87\ In addition, the proposed rule would make it explicit that
modeling must be based on the projected emissions reported under Sec.
550.205(e), or the complex total emissions, whichever is applicable.
---------------------------------------------------------------------------

\87\ In USEPA's case, any proposed facility that has been
identified as a major source of emissions for any given pollutant
must then be evaluated to determine whether that facility would
generate emissions in excess of the Significant Emissions Rate (SER)
for every other air pollutant. BOEM's EETs are designed to
accomplish a similar purpose, namely to identify situations where a
proposed facility's emissions may be potentially significant.
---------------------------------------------------------------------------

This approach relies on the presumption that there would be one EET
applicable at any given location for each precursor or CP. As an
alternative, BOEM could establish multiple EETs for any given pollutant
in those situations, such as for NOX, where the same pollutant is both
a CP and a precursor for another CP. In this latter case, BOEM would
not require modeling of any pollutant except in the case that that
pollutant exceeded a relevant EET.
The proposed rule would provide that a lessee or operator must use
one or more of the following air dispersion models: An air dispersion
model listed in appendix A to appendix W to 40 CFR part 51; an air
dispersion model listed in the Federal Land Managers' Air Quality
Related Values Workgroup Guidance; or another model approved by the
BOEM Chief Environmental Officer. The lessee or operator would also be
required to follow the modeling procedures recommended in 40 CFR part
51 appendix W, as amended, to the extent possible. A lessee or operator
would be required to provide BOEM with a copy of its dispersion
modeling protocol and the associated data and assumptions used to do
its analysis before it conducts such modeling.
Paragraph 550.304(b)--Photochemical Models
The proposed rule would require both dispersion and photochemical
modeling, under a limited number of circumstances. For air
photochemical modeling, the proposed paragraph (b) would also require
lessees and operators use a model approved by the BOEM CEO and follow
the modeling guideline provided in 40 CFR part 51 appendix W, as
amended, to the extent possible. BOEM does not anticipate implementing
a requirement for lessees and operators to conduct single source
photochemical modeling for plan facilities until such time as it has
determined that this modeling would be reasonable and practical for
such lessees and operators, taking into consideration both the
technical feasibility and the costs.
The proposed rule in Sec. 550.304(b) describes BOEM's proposed
photochemical modeling requirements.\88\ Photochemical

[[Page 19776]]

modeling shows the concentration increase onshore of an air pollutant
that is formed as a result of photochemical processes in the
atmosphere. Photochemical modeling would be required only if: (1) The
projected emissions for the relevant precursor air pollutants exceed
the applicable emission exemption threshold; (2) an appropriate
photochemical air quality model is available that either meets the
USEPA's requirements in section 3.2 of 40 CFR part 51, appendix W, or
complies with the FLM's modeling guidance, or has been approved by
BOEM's CEO; and (3) BOEM has determined that adequate relevant
information on background concentrations is available for the relevant
location(s) in a potentially affected State. The proposed rule would
require lessees and operators provide BOEM, upon request, with a copy
of the photochemical modeling protocol and the associated data and
assumptions used to perform the photochemical analysis before the
actual modeling is conducted.
---------------------------------------------------------------------------

\88\ This section indicates that a photochemical model will be
used under certain circumstances so long as it can be approved as an
alternative model under Section 3.2 of Appendix W. This is similar
to what the USEPA is proposing to do, in that the USEPA's proposed
revisions to Appendix W do not solely rely upon explicit use of
photochemical models for each permit situation. Rather, EPA has a
tiered approach with a first tier that uses existing information or
reduced form models in lieu of full photochemical modeling.
---------------------------------------------------------------------------

The USEPA is currently evaluating the feasibility of establishing
and requiring single source photochemical modeling, something that was
technically challenging and generally cost prohibitive in the past.
BOEM is reviewing the USEPA's work in this area. Once BOEM has
determined that the appropriate models are available, photochemical
modeling may be done cost effectively, and the relevant background
concentration data are available, BOEM will consider approving model(s)
for use under this proposed section. Modeling protocols and the
regional exemption studies supporting the EETs will likely allow BOEM
to approve a photochemical model in the year 2020.
In order to make a determination as to the appropriate
circumstances under which single source photochemical models should be
required, BOEM must also establish appropriate EETs as the screening
mechanism. BOEM may develop EETs specific to O3 and
PM2.5 formation, either in addition to or in lieu of
specific SERs or EETs, or utilize reduced form photochemical models as
a screening tool to determine the circumstances under which full single
source photochemical modeling may be required.\89\ BOEM might consider
current and future USEPA regulatory models, assessment techniques, and
related guidance to develop EETs specific to O3 and
PM2.5 formation.
---------------------------------------------------------------------------

\89\ BOEM is considering chemical transport models, including
Lagrangian puff models and Eulerian grid (e.g., photochemical
transport) models, as well. Lagrangian puff models would require a
realistic chemical environment for input, whereas photochemical
transport models typically estimate a realistic chemical
environment. Even though single source emissions are injected into a
grid volume, comparisons with in-plume measurements indicate these
types of models can capture downwind secondary pollutant impacts
when applied appropriately for this purpose. Single source impacts
estimated by photochemical grid models can be done by comparing a
(1) model simulation with all sources and the project source at
preconstruction levels and (2) model simulation with all sources and
the project source at post-construction levels. Alternatively, post-
construction emissions could be tracked with photochemical grid
model source apportionment or source sensitivity model extensions.
---------------------------------------------------------------------------

Paragraph 550.304(c)--Projected Emissions
Section 550.304(c) of the proposed rule would require the lessee or
operator to base its modeling on its maximum projected emissions, as
reported under Sec. 550.205(e), or on the complex total emissions in
those situations where that reporting is otherwise required.
Paragraph 550.304(d)--Meteorology
Section 550.304(d) of the proposed rule would require, that for any
modeling performed, lessees and operators must apply the best available
and most recent meteorological dataset(s), either as directed in 40 CFR
part 51 appendix W, or by using an alternate dataset(s) approved by the
Regional Supervisor. In addition, the proposed rule would require
lessees and operators to create a modeling report documenting all
emissions sources, inputs, parameters, assumptions, procedures,
methods, and results including input and output files, and data upon
which their analyses under subpart C would be based, and to provide
BOEM with copies of all data and access to any programs used in their
modeling.
Paragraph 550.304(e)--Estimates of Ambient Air Concentrations
The proposed rule would specify in Sec. 550.304(e) that, for each
criteria air pollutant resulting from your projected emissions (or
complex total emissions where applicable), the lessee and operator must
estimate the peak incremental concentrations projected in any
attainment area(s) and, separately, in any non-attainment area(s), in
any State, including State submerged lands and onshore. BOEM is
proposing this new requirement because the highest air pollutant
concentration on the onshore area of a State may or may not occur at
the onshore area that is closest to the facility described in the plan.
Depending on the meteorology of the OCS region, the maximum
concentration will likely occur at that point on the shoreline or above
State submerged lands where the emissions are directed by the
prevailing winds. The distinction between the peak attainment and peak
non-attainment areas is important because the evaluation and ERM
criteria are different for impacts to these two kinds of areas.
Section 550.304(e) would require, to the extent practicable,
estimates of the ambient air concentrations of any criteria air
pollutant consider not only the dispersion of each criteria air
pollutant itself, but also the formation of any criteria air pollutant
that may result from the dispersion or presence of any relevant
precursor air pollutant(s). The proposed rule would state specifically
which precursors would be required to be included in the analysis of
PM2.5 and O3.
The proposed rule would also state that BOEM may provide
information through Notices to Lessees to assist lessees and operators
in evaluating existing ambient air concentrations, or changes in such
concentrations over time, if BOEM determines that there is an effective
means of estimating ambient air quality. Under the proposal, if BOEM
has determined that there is an effective means of estimating ambient
air quality and BOEM has established appropriate background
concentration data for any given pollutant, at any given location and
point in time, a lessee or operator would be required to use the
relevant data provided by BOEM. Alternatively, in the event that BOEM
has not determined appropriate background concentration data for any
given pollutant, for any given location, and point in time, a lessee or
operator would be required to use the relevant data from the USEPA for
the closest appropriate location, as specified by the Regional
Supervisor.
Paragraph 550.304(f)--Attributed Emissions
Section 550.304(f) would require that, for the purpose of
calculating the relevant attributed emissions, lessees and operators
conduct modeling of attributed emissions from those locations where
those emissions are most likely to occur, utilizing the most
appropriate line, area, volume, or pseudo point source model that would
most accurately estimate the actual emissions that will result from
MSCs, or other support operations. Under the current practice, in
contrast, modeling is performed on the assumption that all

[[Page 19777]]

attributed emissions originate at the same location as that of a single
stationary facility.
Paragraph 550.304(g)--Documentation and Reporting
The proposed rule in Sec. 550.304(g) would require the lessee or
operator to create a modeling report documenting all emissions sources,
inputs, parameters, assumptions, procedures, methods, and results,
including input and output files, and underlying data upon which its
analysis under this subpart is based. The rule would require the lessee
or operator provide BOEM with copies of the modeling report, copies of
all relevant data and the lessee or operator provide access to any
programs used to perform their modeling.
Section 550.305--How do I determine whether my projected emissions of
criteria air pollutants require ERM?
The proposed rule would require lessees and operators to compare
the results of the modeling conducted under proposed Sec. 550.304 with
the USEPA's Significant Impact Levels (SILs). If the modeling results
are higher than the SILs, ERM would be required as specified in Sec.
550.306, for a short-term facility, or as specified in Sec. 550.307,
for a long-term facility. Under current BOEM regulations, if modeling
indicates an exceedance of the SILs, which the current regulations
refer to as Significance Levels, this triggers the requirement to apply
BACT. The table of Significance Levels in current Sec. 550.303(e) was
based on the table of the USEPA's SILs as they existed in 1980. The
USEPA's tables, however, have been updated since then.
The USEPA's regulation on SILs, at 40 CFR 51.165(b), states that an
emissions source ``will be considered to cause or contribute to a
violation of a national ambient air quality standard'' when such a
source would cause an exceedance of the SILs. Accordingly, BOEM is
proposing to use the SILs to set the level of projected air pollution
increase at a measurement point either onshore or above State submerged
lands, that, if exceeded, ERM may be evaluated and controls may be
required. BOEM is proposing to cross-reference the USEPA's table of
SILs so, if there is an update or addition that results in a change to
the USEPA table, that change would automatically become incorporated
into BOEM's regulatory standards.
Since PM2.5 is both emitted and formed in the
atmosphere, lessees and operators would be required to add the results
of their air dispersion modeling for direct PM2.5 emissions
to the results of their photochemical modeling, if required under
proposed section 550.304, before comparing the results with the
PM2.5 SILs. If the resulting sum exceeds a SIL for
PM2.5 for any averaging time, the operator would be required
to apply ERM. As set out in proposed section 550.304 and explained
above, this additional modeling for PM2.5 would only be
required if the relevant photochemical models and background
concentration are available.
In contrast to the other criteria air pollutants, the USEPA's
current regulations do not set a SIL or AAI for O3. Rather
than determine equivalent standards for O3 at the present
time, BOEM is proposing to require ERM based on emissions precursors of
O3 when modeling would indicate the NAAQS for O3
would be exceeded. Accordingly, lessees and operators would be required
to add the results of their photochemical modeling, if required under
section 550.304, to the existing background concentrations and
determine if a NAAQS for O3 would be exceeded for any
averaging time. If any NAAQS is exceeded, the lessee or operator would
be required to apply ERM. BOEM solicits comments both on this approach
and whether photochemical modeling should be required in all cases.
Alternatives could include reserving a full scale analysis until such
time as the USEPA has established a SIL for O3, applying a
consultative process between applicant and BOEM consistent with current
appendix W until such time as revisions to appendix W have been
finalized and the USEPA has established or recommended significance
levels.
Under the proposed rule, BOEM would eliminate the standard for
TSPs, which measures the ambient concentration of particulates having a
diameter of less than 100 micrometers. Instead, BOEM would formally
adopt by cross-reference the two new standards that the USEPA created
in place of the TSP standard: PM10 and PM2.5.
PM10 represents an ambient air concentration standard for
particulates of a diameter of 10 micrometers or less, while
PM2.5 represents an ambient air concentration standard for
particulates of a diameter of 2.5 micrometers or less. The USEPA's
annual and 24-hour averaging time SILs for PM10 are the same
as those which BOEM currently applies to TSP.\90\ The current
regulation's reference to TSP includes particulates of a larger size
than those covered by the USEPA's definition of PM10. At the
time the current regulation was promulgated, the use of a TSP standard
reflected the USEPA practice; however, the USEPA's standard for
PM10 has been in place since 1987. Because the USEPA
standard has been in place for many years, the majority of OCS
operators have already adopted this standard, and BOEM has largely
replaced TSP with PM10 in the GOM.
---------------------------------------------------------------------------

\90\ The annual SIL for TSP in the current BOEM regulations has
an equivalent for PM10 because the USEPA has not revoked
the annual SIL for PM10, although the USEPA revoked the
annual NAAQS for annual PM10 subsequent to the
publication of BOEM's air quality regulations.
---------------------------------------------------------------------------

The existing SILs for other criteria air pollutants in BOEM's
current regulations would not change as a result of this revision in
BOEM's regulations, because they are currently set at the same levels
as those set by the USEPA. The proposed rule would, however,
incorporate the addition of new SILs established by the USEPA, since
the adoption of BOEM's original air quality rule. Going forward, there
is the possibility that the USEPA will further change the SILs, or add
new SILs, in which case BOEM's decision to cross-reference the USEPA's
regulation would automatically cause the BOEM significance threshold
rates to change, as well.
There are some circumstances where the USEPA has not established a
SIL for a given CP or in which it has established only an interim SIL
that it or the relevant State air quality regulatory authority may also
use in evaluating the impacts of a proposed facility. In some
circumstances, the USEPA may have established one or more SILs in its
regulations and an additional interim SIL(s), typically for some other
averaging time(s), outside of its regulations. In other cases, the
USEPA may have repealed a SIL without establishing a new one. Thus,
there may be situations where a lessee or operator may propose a plan
that exceeds the relevant EETs, then perform modeling only to find
there may not be a relevant SIL to compare against its incremental
emissions or a situation where it may be unclear which SIL(s) to use.
In similar situations where the USEPA or the State would issue an air
quality permit, the USEPA or the relevant State permitting authority
has issued permitting guidance to supplement its regulations. The
proposed rule does not contain a provision on this topic and BOEM
solicits comments on how best to address this issue.
BOEM also requests comment on what BOEM should do about NAAQS that
do not have corresponding SILs in the USEPA regulations; comments on
the following two alternative approaches are particularly welcome. One
alternative would be for BOEM to

[[Page 19778]]

require in the final rule that, for any NAAQS (pollutant and averaging
period) for which there is no SIL in 40 CFR 51.165(b)(2), lessee and
operators must apply the appropriate SIL being used by the most
affected State (at the point where the incremental emissions caused by
the facility would be highest). Another alternative would be for BOEM
to establish its own interim SILs based on the USEPA's interim SILs, to
be used unless and until the USEPA finalizes appropriate SILs in its
regulation at 40 CFR 51.165(b).
Section 550.306--What ERM are required for a short-term facility?
Proposed Sec. 550.306 would set forth the requirements for ERM for
both criteria and major precursor pollutants on a short-term facility
when modeling shows the facility will cause emissions to exceed the
SILs, or when modeling will indicate a violation of the NAAQS for
O3. ERM would also be required when emissions of VOCs exceed
the EETs under the proposed Sec. 550.303(b). Unlike the proposed
requirements for a long-term facility, the proposed control
requirements for a short-term facility would be the same for criteria
and major precursor pollutants.
Under BOEM's existing regulations in Sec. 550.303(h), ``[t]he
lessee shall apply BACT to reduce projected emissions of any air
pollutant from a temporary facility which significantly affects the air
quality of an onshore area of a State.'' The current regulations also
explicitly exempt temporary facilities from the requirements for
controls set out in current regulations in Sec. 550.303(g), which
require additional analysis on top of the application of BACT for non-
temporary facilities. In contrast, the proposed rule would require
lessees and operators to apply only operational controls and/or
equipment replacements, but not BACT in those situations where a SIL or
VOC EET is exceeded. The proposed rule, like the current regulations,
would not require additional AAI analysis after the application of ERM
for a short-term facility.
Under the proposed rule, an ERM analysis would start by identifying
all available non-BACT control measures that would be relevant to the
emissions of the pollutant(s) for which ERM would be required. The
lessee or operator would then determine which of these are technically
feasible. BOEM is proposing to define ``technically feasible'' in
proposed Sec. 550.302. The proposed rule would also add a requirement
that a ``demonstration of technical infeasibility must be clearly
documented and must show, based on physical, chemical or engineering
principles, that technical difficulties would preclude the successful
use of the applicable emission control technology or methodology.'' The
lessee or operator would rank the technically feasible control measures
by their ability to reduce actual emissions, based on the overall
emission control efficiency (e.g., percent pollutant removed, or
emissions per unit of product) for each alternative. The lessee or
operator would then evaluate and select the non-BACT ERMs that are
technically feasible and that are designed to limit the facility's
projected emissions to the greatest practicable extent, taking into
consideration the effectiveness of emissions control(s). Then the
lessee or operator would be required to evaluate the cost effectiveness
of each of the selected technically feasible operational controls in
order to determine its economic impacts and feasibility. To justify
elimination of an option on economic grounds, the lessee or operator
should demonstrate that the costs of pollutant removal for that option
are disproportionately high. As an alternative, lessees or operators
could substitute permanent emissions credits for operational controls
or equipment replacements, at their discretion.
If no technically feasible operational controls or equipment
replacements could be implemented cost effectively and the projected
emissions affect only attainment areas, then no ERM would be required
for the pollutant exceeding a standard other than those that the lessee
or operator proposed in its plan. If no technically feasible
operational controls or equipment replacements could be implemented
cost effectively, and the projected emissions would affect a non-
attainment area, then the Regional Supervisor could require the
implementation of other ERM, including BACT, as a condition of
approving the lessee's or operator's plan. Such ERM could be required
on either a permanent or temporary basis, depending on the
circumstances and location of the proposed facilities. If this ERM
includes any proposed BACT, then the lessee or operator would be
required to provide a description of the associated energy,
environmental, and economic impacts, and other costs.
The nature of any ERM could vary widely depending on the issue
being addressed and the location of the relevant operations. Examples
of such measures could be: Running specific equipment at optimal
efficiency for certain periods of time, only operating certain
equipment on specific days or for some number of days in a month or
week or at specific times of day, etc. They could vary based on the
existing background levels of pollution, the climatic conditions and
the type of plan proposed. Operational controls could involve using
specific types of fuel or specific types of combustion technology or
limiting the use of certain equipment to a specific purpose or
circumstance. They could also involve keeping certain equipment at a
specified distance from other equipment or facilities, etc.
The purpose of implementing such controls would be to keep the
volume of air pollutants produced in connection with the operations
conducted under a plan within a range such that none of the AAQSB would
be violated, either on a temporary or ongoing basis, thereby ensuring
such operations comply with BOEM air quality requirements.
Paragraph (b) of the proposed section would specify what must be
included in a lessee's or operator's plan describing the results of the
ERM analysis. This would consist of: An evaluation of the ERM selected,
quantifying and verifying the emissions reductions measures and
associated costs; a description of how the selected operational
controls or replacement equipment meets the criteria in Sec. 550.309
for ERM; and a calculation of the revised projected emissions (or
complex total emissions, where applicable), taking into account the
selected operational controls or replacement of equipment.
The proposed rule would specify that, if an operator has committed
to apply appropriate operational controls or replacement of equipment,
in the case of a plan affecting only an attainment area, or committed
to apply appropriate ERM, with respect to a plan affecting a non-
attainment area, BOEM could approve the plan, provided all other
applicable requirements have been met. However, if BOEM were to have a
reason to believe a lessee's or operator's projected emissions may
cause the NAAQS to be exceeded, the Regional Supervisor could require
additional data, analysis, or modeling to demonstrate compliance with
the NAAQS or might require additional ERM so that the NAAQS are not
exceeded.
Section 550.307--What ERM are required for a long-term facility?
Unlike short-term facilities, long-term facilities are generally
intended to remain in operation for many years. Correspondingly, they,
in conjunction with their MSCs, generally emit considerable amounts of
air pollutants on an ongoing basis. Because of this, long-term
facilities warrant more stringent air quality compliance requirements.
This proposed section

[[Page 19779]]

describes the air quality control analysis required of such facilities.
Proposed Sec. 550.307 would set forth the requirements for ERM on
a long-term facility when modeling shows the facility will cause
emissions exceeding the AAIs or SILs (or when it would cause a
violation of the NAAQS for O3). This proposed section would
expand upon the existing control requirements for facilities in Sec.
550.303(g) of the existing regulations. The current regulations mandate
the application of BACT whenever a facility's emissions exceed the
SILs, but they then allow ``the application of additional emission
controls or through the acquisition of offshore or onshore offsets.''
The proposed rule eliminates the preference for BACT and provides for
additional options, including equipment swaps and operational controls.
As is the case with current BOEM regulations, the requirements of this
section differ depending on whether the potential impacts of any
proposed facility would affect only attainment areas or whether non-
attainment areas might also be affected. More stringent air quality
requirements, of course, apply to situations where an area already
exceeds a relevant pollution standard than in an area that is below
that standard (i.e., has better overall air quality). BOEM has not
proposed a definition of what ``affect'' means in this context but
solicits comments on how this determination should be best made.
One alternative would be that a facility that does not cause an
exceedance of a SIL at any location in a State would not be considered
to be one that impacts an affected area of the State. Conversely, any
location at which a facility's projected emissions could cause an
exceedance of a SIL would constitute an affected area of a State for
the purpose of this rule. The difficulty with this approach, however,
lies in the fact that there may be many locations at which a SIL is
exceeded and the boundary of this exceedance may be difficult or
impractical to determine--particularly in the context of the non-
attainment areas.
Another alternative would be to require that any modeling be done
with receptors just inside the outer boundary of a non-attainment area
or at the attainment/non-attainment area boundary nearest to, or
directly downwind of, the proposed facility. If modeling indicates that
that no AAQSB would be exceeded at that point, then no non-attainment
area would be considered affected by the proposed facility.
There may be other approaches to handling the determination of
affected areas. BOEM would welcome suggestions or alternatives for how
best to address this issue.
Paragraph 550.307(a)--Control of Emissions of VOCs From a Long-Term
Facility
The proposed rule at Sec. 550.307(a), like the current regulation,
separates requirements for controls of VOCs from requirements for
controls for other air pollutants. If the projected emissions of VOCs
exceed an emission exemption threshold, then the lessee or operator
would be required to apply controls. The controls required would depend
upon the attainment status of the areas of the State(s) potentially
affected by the emissions. If the projected emissions affect, or have
the potential to affect, only attainment areas for O3 and
PM2.5, then the lessee or operator would be required to
propose ERM, excluding BACT, and would be required to demonstrate the
proposed ERM would reduce the emissions of VOCs to the lowest
practicable and reasonable rate (i.e., the lowest rate that can
reasonably be achieved). If any designated non-attainment area for
O3 or PM2.5 is affected, then the lessee or
operator would be required to evaluate all the potentially applicable
ERM, including BACT, and propose sufficient ERM to reduce VOC emissions
below the applicable emission exemption threshold. For any proposed
BACT, the operator or lessee would be required to provide a description
of the associated energy, environmental, and economic impacts, and
other costs.
Paragraph (a)(3) of the proposed section would provide for an
exception to the requirement to reduce VOC emissions when they affect a
State coastal area where an increase in VOCs would not lead to the
formation of increased O3 or would lead to a decrease in the
formation of O3. The proposed rule would also provide that
emissions credits could be utilized as an alternative to any other
relevant ERM, regardless of the attainment or non-attainment status of
any area that would potentially be affected by the projected emissions
associated with any lessee or operator's proposed plan.
Paragraph 550.307(b)--Control of Emissions of Criteria Air Pollutants
From a Long-Term Facility
For emissions of criteria air pollutants, the controls that would
be required for long-term facilities also depend on the attainment
status of the area affected by the projected emissions. If all areas
affected by the projected emissions are designated attainment areas,
then the lessee or operator would be required under Sec. 550.307(b)(1)
to evaluate all the potentially applicable ERM, excluding BACT, and
propose sufficient ERM to reduce the ambient impact of the projected
emissions and to conduct refined modeling to show the effects of the
ERM, using the process described in proposed Sec. 550.306(a)(1)
through (4) for a short-term facility. Once the appropriate ERM have
been determined, the lessee or operator should re-conduct modeling to
evaluate the effect of applying ERM to reduce emissions and to
determine whether or not the operator or lessee's reduced emissions
would cause an exceedance of the AAIs. Lessees and operators would be
required to combine the ambient air effects of their emissions with the
emissions from other onshore and offshore sources which contribute to
the consumption of the maximum allowable increases above the baseline
concentrations for each air pollutant and baseline area, as established
in 40 CFR 52.21. In conducting this additional modeling, operators
would be required to use the ambient air concentration data, as
specified in proposed Sec. 550.304(e)(2). If this modeling shows that
ERM is not sufficient to reduce the projected concentration increases
below the AAIs applicable to the potentially affected State, then the
lessee or operator would be required to apply additional ERM and
perform additional modeling until such efforts confirm that no AAIs
would be exceeded. As discussed above, this was the intent expressed in
the preamble to the BOEM's current rule. This proposed rule would make
this intent clear in the regulatory text itself.
Once this additional modeling shows the ERM is sufficient to reduce
the projected concentrations below the AAIs applicable to the
potentially affected State, then the lessee or operator would be
required to compare the resulting design concentration of each criteria
air pollutant with the NAAQS. If any of the NAAQS are shown to be
exceeded, the lessee or operator would be required to apply additional
ERM and perform additional modeling until it determines none of the
NAAQS would be violated.
As discussed earlier, the current regulations use the MACIs in
place of the AAIs for determining whether long-term facilities have
sufficiently reduced their impacts on attainment areas. The MACIs were
based on the AAIs at the time the current rule was promulgated. While
BOEM is now proposing to cross-reference the AAIs, it is also
considering whether other standards would be better. Particularly, BOEM
is considering whether it would be better

[[Page 19780]]

to use standards that are based on a percentage of the level of the
NAAQS, rather than the AAIs. BOEM would appreciate comment on this
issue and on what standards to set. BOEM also requests comments on the
most appropriate method for defining the size and extent of the
relevant ``baseline areas'' for the purpose of conducting the AQRP
analysis.
Under the proposed rule at paragraph 550.307(b)(2), if projected
emissions affect any area designated as a non-attainment area, then the
lessee or operator would be required to evaluate all the potentially
applicable ERM, including BACT, and propose sufficient ERM to reduce
the ambient impact of its emissions of all criteria air pollutants
below the applicable SILs at 40 CFR 51.165(b)(2). The proposed rule
would then require a lessee or operator to conduct modeling using the
revised projected emissions and compare the results with the SILs. If
photochemical modeling would be required under Sec. 550.304, then the
lessee or operator would be required to also perform photochemical
modeling and add the results of that modeling to the results of the
additional dispersion models. If the modeling results exceed any SIL
for any criteria air pollutant for any averaging time, then the lessee
or operator would be required to apply additional ERM until additional
modeling demonstrates all projected emissions have been fully reduced
below the SILs for all criteria air pollutants for every applicable
averaging time.
Paragraph 550.307(c)--Exceptions to the ERM Requirement
The proposed rule at Sec. 550.307(c) would also provide that, for
any averaging time other than an annual period, a facility's projected
emissions may cause an ambient impact that exceeds an applicable AAI
one time during any rolling 12-month period for any given criteria air
pollutant at any one location and still be considered to have fully
reduced emissions. This provision is retained from the language in
existing regulation Sec. 550.303(g)(2)(i)(B), which states: ``For any
period other than the annual period, the applicable maximum allowable
increase may be exceeded during one such period per year at any one
onshore location;'' however, slight changes have been made in the
wording for clarity.
Additionally, this proposed paragraph would provide that if an
operator or lessee's projected emissions of NOX potentially
affect a State coastal area, but would not cause an increase, or would
cause a reduction, in the formation of O3, then no ERM are
required for NOX. However, this exception would not apply if
the potentially affected area is an attainment area for NO2
and the lessee or operator's analysis indicates that the AAIs for
NO2 would be exceeded in the absence of such ERM or if the
potentially affected area is a non-attainment area for NO2.
This proposed paragraph would also provide an exception if the
implementation of a plan under these regulations would compromise the
safety of the operation of the facility, and such implementation of any
AAQSB cannot be otherwise addressed.
Paragraph 550.307(d)--NAAQS Requirement Applicable to All Plans
The proposed rule at Sec. 550.307(d) would contain a provision,
consistent with the current BOEM regulations at Sec.
550.303(g)(2)(i)(B) (``No concentration of an air pollutant shall
exceed the concentration permitted under the national secondary ambient
air quality standard or the concentration permitted under the national
primary air quality standard, whichever concentration is lowest for the
air pollutant for the period of exposure''), stating no concentration
of an air pollutant could exceed the concentration permitted under any
primary or secondary NAAQS, whichever concentration is lowest for the
air pollutant for the period of exposure. The proposed rule would state
that NAAQS may not be exceeded, even for a short-term facility.
Paragraph 550.307(e)--Emissions Credits
The proposed rule would clarify that a lessee or operator may
propose to use emissions credits to achieve the equivalent reduction of
emissions for any criteria air pollutant as an alternative to any other
ERM, regardless of the attainment status of the State area affected by
its facility's potential emissions.
Section 550.308--Under what circumstances will BOEM require additional
ERM on my proposed facility or facilities?
The purpose of this proposed provision is to provide a safeguard to
the plan approval process, such that any approval of a facility made
according to these regulations does not cause a violation of an
applicable air quality control standard. Because all of BOEM's plan
reviews are done on a prospective basis, it is possible the impacts of
the implementation of such a plan could cause an adverse effect on a
State that was not anticipated. This provision in the proposed rule
provides a mechanism for State and local government entities, and
certain Federally-recognized Indian tribes, that might be adversely
affected by the approval of a plan or a RUE, pipeline ROW, or lease
term pipeline application to raise objections on the basis of data or
information that may not have been available to BOEM at the time a plan
was originally approved. The current rule contains a similar provision
that applies only to States.
The current regulations, under Sec. 550.303(j), provide ``[i]f . .
. the Regional Supervisor determines or an affected State submits
information . . . which demonstrates . . . that projected emissions
from an otherwise exempt facility will, either individually or in
combination with other facilities in the area, significantly affect the
air quality of an onshore area, then the Regional Supervisor shall
require the lessee to submit additional information to determine
whether emission control measures are necessary.''
Paragraph 550.308(a)--Regional Supervisor Review
The proposed rule at Sec. 550.308(a) would expand upon this
provision by specifying the Regional Supervisor could require the
lessee or operator to apply additional ERM on either a temporary or
permanent basis, depending on the circumstances, if he/she determines
the projected emissions, or, where applicable, complex total emissions,
may cause or contribute to a violation of a NAAQS, based on (1)
information submitted by a State, or a local government, or a
Federally-recognized Indian tribe; (2) information resulting from a
cumulative impacts analysis conducted for a NEPA analysis; (3) a
compliance review of a proposed plan under subpart B, Sec. 550.232(b)
for an EP, or Sec. 550.267(c) for a DPP or DOCD; or (4) the
declaration by an adjacent State, or the USEPA, of an air quality
emergency for a location that may be affected by air emissions
generated by operations.
Paragraph 550.308(b)--Lessee's or Operator's Right To Challenge
The proposed rule would provide in Sec. 550.308(b) any lessee or
operator affected by the requirements of this section would be given
notice of the Regional Supervisor's determination under paragraph (a)
of this proposed section, as well as an opportunity to present
additional information and analysis for review by the Regional
Supervisor. Under the proposed rule, if the lessee or operator presents
the Regional Supervisor with additional information and analysis, the
Regional

[[Page 19781]]

Supervisor would reassess whether the projected emissions, or complex
total emissions, might cause or contribute to a violation of any NAAQS,
and whether additional ERM would be required for the facility. Similar
to the current regulations, under the proposed rule, the Regional
Supervisor would then notify the affected State, or Federally-
recognized Indian tribe, and explain the reasons for this
determination.
Section 550.309--What requirements apply to my ERM?
The proposed rule would provide explicit requirements to ensure the
sufficiency, effectiveness, and control efficiency for a lessee's or
operator's ERM. It also would specify how a lessee or operator could
use emissions offsets.
Paragraph 550.309(a)--Sufficiency
Under the proposed rule at Sec. 550.309(a), a lessee's or
operator's proposed ERM would need to be sufficient to achieve actual
emissions reductions corresponding to those reported in the plan for
the duration of the plan's operations under all reasonably foreseeable
conditions. Under the proposed rule, the Regional Supervisor would
review a lessee's or operator's proposed ERM on a case by case basis
and make a determination whether such measures met the applicable
criteria.
Paragraph 550.309(b)--Effectiveness
Under Sec. 550.309(b), the lessee or operator would need to
continually ensure the effectiveness of its ERM for the duration of the
plan's operations under the proposed rule. If emissions reductions
measures become disabled or unavailable, the lessee or operator must
immediately notify the Regional Supervisor and replace such ERM with
others of equal or superior effectiveness within 30 days of discovering
the disability or unavailability, unless the Regional Supervisor
approves an extension not to exceed 90 days.
Paragraph 550.309(c)--Control Efficiency
The proposed rule at Sec. 550.309(c) would specify that the
analysis of the proposed ERM would need to reflect actual ECE. The
proposed rule would require a lessee or operator to substantiate any
ECEs it projects and provide sufficient evidence to justify its
projected ECEs to the satisfaction of the Regional Supervisor. The rule
would further specify at Sec. 550.309(c)(1) that, should the
substantiating data indicate a range of efficiencies, the lessee or
operator would be required to utilize the more conservative estimates
(i.e., those that would result in lower ECE) in its analysis and
modeling. The intent of this provision is to ensure the proposed
benefits that would result from BACT and/or other emissions controls
would not be over-estimated, in order to ensure any controls that are
proposed would be sufficient to actually reduce the emissions of a
proposed facility to the levels projected in the analysis conducted
pursuant to subpart C. Consistent with this, a further requirement is
proposed at Sec. 550.309(c)(2) whereby ECE estimates of 100 percent
ECE would generally not be considered acceptable, except in cases where
there is clear and convincing and/or historical evidence to justify
their use. This requirement recognizes the fact there are virtually no
emissions control mechanisms that can entirely eliminate all potential
air pollutant emissions, and it is both unrealistic and unreasonable to
make such an overstated estimate, without definitive evidence of its
accuracy.
Paragraph 550.309(d)--Emission Reduction Monitoring
Further, under Sec. 550.309(d), if ERM would be required in an
approved plan, then the proposed rule would authorize the Regional
Supervisor to require lessees and operators to provide information
needed to verify the effectiveness and efficiency of the proposed ERM.
The proposed rule states that a lessee or operator with a plan that is
approved subject to the application of BACT must ensure that the
emissions associated with each emissions source for which BACT is
required complies with the emissions verification requirements of Sec.
550.311 of this subpart. The rule further states that the Regional
Supervisor may also require the installation of emissions measurement
meters if the Regional Supervisor determines that such meters are
necessary to ensure compliance with this requirement (i.e., that other
alternatives may not be sufficient to ensure compliance).
Paragraph 550.309(e)--Emissions Credits
The purpose of acquiring an emissions credit is to cause a
reduction in the emissions of a given pollutant from a business or
activity unrelated to the plan, so that the total concentration of a
given pollutant within a given area will not increase (as a result of
the operations associated with a plan) beyond a permissible level.
The proposed rule at Sec. 550.309(d) would set forth requirements
for emissions credits. First, the lessee or operator would be required
to acquire emissions offsets from emissions source(s), either offshore
or onshore, that affect the air quality of the same AQCR). Second, for
a CP, the emissions credits that the lessee or operator proposes would
need to provide a net air quality benefit for the same pollutant; for a
precursor pollutant, any emissions credits that a lessee or operator
proposes would need to provide a net air quality benefit for that CP
for which the pollutant is a precursor. Third, the lessee or operator
would need to demonstrate to the Regional Supervisor that the emissions
credit it proposes binds it and any other parties who agree to lower
their emissions. Fourth, the lessee or operator would need to also
demonstrate that any emissions reductions will last for the entire
period of operations covered in its plan. The Regional Supervisor might
periodically require the lessee or operator to certify that the
emissions reductions are still in place. Fifth, any emissions credits
would need to reduce emissions below rates otherwise required by law.
Sixth, in addition to BOEM, the lessee or operator would be required to
notify the appropriate State air quality control jurisdiction of its
proposal to acquire emissions credits, modify the permit for the
underlying onshore facility to reflect the proposed reduction in
emissions and, if necessary, its need to revise the State
Implementation Plan to include the information regarding the emissions
credits the lessee or operator has acquired. Seventh, emissions credits
would be allowed in those circumstances where BOEM could readily verify
the historical emissions from the facility to be used for the emissions
credit, and the emissions reduction associated with the acquired
emissions credit. Eighth, the approval of an emissions credit would not
be granted unless the reductions in emissions associated with the
credit are verifiable by an appropriate State, tribe or federal agency
(primarily through the modification of the air emissions permits for
the relevant onshore facility). Finally, the proposed rule would
specify that nothing in these regulations is intended to restrict
emissions credits from being obtained and divided among multiple
lessees or operators.
If an OCS lessee or operator proposes to use emissions credits as
an emission reduction measure (ERM), in lieu of BACT, operational
controls or the replacement of equipment used on the OCS, then that
lessee or operator would be responsible for ensuring that the
reductions are permanent and verifiable.

[[Page 19782]]

In the event that a lessee or operator elected to reduce the pollutant
emissions of an onshore facility to offset corresponding emissions for
a new facility proposed on the OCS, that lessee or operator could
ensure that the reductions are permanent and verifiable by notifying
the relevant State air quality regulatory body and seeking a
modification of the permit for the underlying onshore facility to
reflect the proposed reduction in emissions. The State could then
update the permitted level of emissions which would ensure compliance
with the reduced emissions requirements on an ongoing basis. The State
could also update its SIP, if appropriate, and modify its reporting to
the U.S. Environmental Protection Agency. BOEM does not believe that
this process would be unduly burdensome to the States or that it would
require any State-funded monitoring or compliance activities beyond
those that are already in place or contemplated.
Rather, BOEM believes that this process would largely be beneficial
to the States, in that the reduction in air emissions of onshore
facilities, beyond those that would otherwise be legally required,
could cause a net air quality benefit to the States and localities
affected. Such a change could also allow a greater level of economic
development, and a greater number of approvals for additional
stationary sources onshore than might otherwise be the case (in the
absence of the emissions credit). For these reasons, BOEM believes that
the potential use of emissions credits by lessees or operators would be
neither onerous nor unreasonable.
The proposed rule would allow emissions credits to be obtained and
divided among multiple lessees or operators (presumably located near to
one another in the vicinity of the State) in order to spread the costs
of complying with air quality requirements over a broad area, or for
any other reason.
The manner in which the proposed rule would have the potential to
affect the relationship between the federal and State governments has
to do with a situation in which an OCS lessee or operator proposes to
use emissions credits as an emission reduction measure (ERM), in lieu
of BACT. In the event that a lessee or operator elected to reduce the
pollutant emissions of an onshore facility to offset corresponding
emissions for a new facility proposed on the OCS, that lessee or
operator would be required to notify the relevant State air quality
regulatory body and arrange for the modification of the permit for the
underlying onshore facility to reflect the proposed reduction in
emissions. The State could then update the permitted level of emissions
which would ensure compliance with the reduced emissions requirements
on an ongoing basis. The State may also need to update its SIP, as
appropriate, and modify its reporting to the USEPA. Lessees have not
typically utilized emissions credits as a pollution mitigation measure
in the past. BOEM solicits comments on the practicality and potential
costs associated with the implementation of these proposals at the
State level, as well as comments on how these proposals could most
effectively be implemented in coordination with the States.
Paragraph 550.309(f)--Emission Reduction Measures
Under proposed Sec. 550.309(f), unless otherwise specified, the
lessee or operator could employ any operational control, equipment
replacement(s), BACT, or emissions credit, on either a temporary or
permanent basis, to reduce the amount of emissions that would occur in
the absence of such measures. The proposed paragraph would also provide
that any proposed ERM would become a condition of its plan upon
approval and could be required on either a permanent or temporary
basis, depending on the circumstances and location of the proposed
facilities.
In addition, the rule would clarify that any lessee or operator
proposing a plan that includes equipment replacement would be subject
to compliance with all other applicable federal regulations, including
those of the USCG.
Section 550.310--How will revisions to the ambient air standards or
benchmarks affect my plan?
Paragraph 550.310(a)--Review of Plans
The proposed rule at Sec. 550.310(a) specifies that BOEM would
review air pollutant emissions data in a plan according to the AAQSB
that are in effect on the date the plan is deemed submitted. Because
BOEM's regulations would cross-reference the USEPA's standards, BOEM
would make the appropriate changes to its review of plans if the USEPA
revised such standards.
Paragraph 550.310(b)--Proposed Plans
The proposed rule at Sec. 550.310(b) would specify that all
activities described in initial, revised, modified, and supplemental
plans would be required to comply with the AAQSB in effect on the date
the plan is deemed submitted.
The proposed rule, however, would provide exceptions in two
situations. First, under Sec. 550.310(b)(1), if a plan were deemed
submitted shortly after the effective date of a new or revised AAQSB,
and the lessee or operator believed the immediate application of the
new or revised AAQSB would be impracticable or would otherwise impose
an unreasonable hardship on its proposed operations, then the lessee or
operator would be able to request a deferral from the requirement to
comply with the new or revised standard. The Regional Director, with
the concurrence of the Director, would review the request and would
have the discretion to grant a temporary deferral, not to exceed two
years, from compliance with the new or revised AAQSB based upon a
finding of impracticability or undue hardship. Second, under Sec.
550.310(b)(2), for any proposed plan, upon a finding that noncompliance
with a new or revised AAQSB would not significantly affect the air
quality of any State onshore or over State submerged lands, the
Director would be able to grant a departure from compliance with the
revised AAQSB. The Director would have the discretion to condition the
departure upon any requirement(s) deemed necessary to avoid causing or
contributing to a violation of the pre-existing NAAQS. This exception
would account for situations in which the USEPA could revise or add an
ambient air quality standard or benchmark that would not be relevant to
OCS operations or that would go beyond BOEM's mandate to prevent
significant effects on the air quality of a State, would be
impracticable, or would otherwise impose an unreasonable hardship.
Paragraph 550.310(c)--Approved Plans
Under the proposed rule, if a lessee or operator is operating under
an approved plan, it would be required to resubmit a plan for a
periodic air quality review no more frequently than ten years after
BOEM's previous approval of the plan. This provision would be added in
furtherance of the objective of section 5(a)(8) of OCSLA, which
requires BOEM to ensure compliance with the NAAQS, and which makes no
exceptions with respect to previously approved plans. All of the
applicable requirements of this subpart in effect on the date of
resubmission would apply on the same basis to a resubmitted plan as for
an initial plan. BOEM requests comments on this provision, particularly
with respect to the potential impact on lessees and operators.
In order to ensure that the lessee or operator's emissions remain
compliant with OCSLA's air quality mandate,

[[Page 19783]]

starting in 2020, subsequent to the date of the Notice, BOEM proposes
to conduct periodic reviews of plans approved prior to the effective
date of the new exemption thresholds. At that point, each lessee or
operator whose plan was approved prior to the effective date of this
proposed rule would be required to resubmit its plan for a new air
quality review on a schedule listed in the proposed rule. Although the
length of time required between the original plan review and the
subsequent follow-up review would vary, in no case would a lessee or
operator be required to re-submit its plan for an air quality review
more than once every ten years.\91\ A plan initially submitted or
resubmitted pursuant to this proposed provision would be required to
comply with the provisions of Sec. 550.205 as they exist at the time
the plan is submitted, using the most current data on emissions factors
and MSC emissions, and such a plan would, in all cases, be reevaluated
against the EETs and formulas as they exist at the time of the plan
resubmission, rather than those in effect at the time the plan was
originally approved.
---------------------------------------------------------------------------

\91\ Unless the lessee or operator were required to re-submit a
plan for reasons unrelated to the ten-year periodic review cycle
(i.e., because it was proposing to change the plan schedule, add
additional equipment or for some other reason).
---------------------------------------------------------------------------

When a plan is resubmitted under this provision that plan would be
required to include estimates for the annual projected emissions for
the subsequent ten years or for however long the facility would be
expected to remain in operation, whichever is shorter. With respect to
the emissions calculations for any given emissions source, the
resubmitted plan would be required to account for the most recent
available data on the actual emissions of that emission source. Under
the proposal, if a plan would indicate an exceedance of any applicable
emission exemption threshold, all applicable requirements of this
subpart would apply as for an initial plan.
For plans that were approved prior to the effective date of this
rule, the lessee or operator would be required to submit a new plan for
a new air quality review of its existing facilities according to a
schedule in a table listed in the proposed rule. This table would
require that the oldest plans be submitted first for re-review and that
the most recently approved plans would be re-submitted last, according
to the same ten-year review cycle. In each case, each plan would be due
the same month as the month in which the plan was originally approved.
After the year 2023, plans would be re-reviewed every ten years;
and the plan resubmission would be required in the month of the tenth
anniversary of the initial plan approval, or the month of the tenth
anniversary of the approval of a revised, modified, resubmitted or
supplemental plan, whichever is later.
If a lessee or operator proposes to make a change to the equipment
on its existing facility or facilities in a year or years when its plan
already anticipated operations, and its proposed change would result in
an increase in air pollutant emissions from that equipment for any air
pollutant, the lessee or operator would be required to submit a revised
plan, not simply a plan that describes the specific change being
proposed.
The proposed rule would provide that if a lessee or operator fails
to submit a revised plan as required under this section, then the
previous approval of its plan would be revoked. In this circumstance
the lessee or operator could also be subject to civil penalties or
other appropriate sanctions, including the requirement to cease
operations.
Section 550.311--Under what circumstance will I be required to measure
and report my actual emissions?
The purpose of this section is to describe under what circumstances
a lessee or operator would be required to demonstrate its actual
emissions have been and are in compliance with its previously approved
plan(s).
Paragraph 311(a)--Compliance Demonstration Conditions
Paragraph (a) of this proposed section would provide that
facilities described in plans that were approved by BOEM under the
listed conditions would be required to measure actual emissions: (1) If
a plan is approved subject to the implementation of BACT or emissions
credits; (2) if any emissions source on your facility uses any engine
or equipment that is neither certified by the USEPA for domestic use in
the U.S. nor MARPOL-compliant; (3) if the Regional Supervisor
determines that lessees or operator's projected emissions, complex
total emissions, for any criteria or precursor air pollutant,
calculated on either an annual basis or on the basis of a 12 month
rolling sum, may significantly underestimate the actual emissions,
based on either historical data or ambient air monitoring; or, (4) if
BOEM determines that your facility is causing or contributing to an
exceedance of the NAAQS in any State.
Paragraph 550.311(b)--Emissions Reporting Requirements
For lessees and operators who would be required to measure and
report actual emissions, proposed subsection (b) would state several
basic requirements for measurement and reporting of actual emissions.
Lessees and operators that are required to measure and report emissions
would be required to include enough of the emissions sources to ensure
that the actual emissions associated with facilities and MSCs operating
under an approved plan are consistent with the projected emission
limits approved for that plan. In other words, they would be required
to demonstrate that a sufficient number of their large emissions
sources are at or below the projected emissions for that equipment so
that the emissions associated with the remaining emissions sources
would not be sufficient to cause an exceedance of the projected
emissions limits approved in the plan.
Under the proposed rule, each lessee or operator would be required
to consider every source that was included in its approved plan in
addition to any source that would be classified as part of the
projected emissions if the plan were resubmitted under the current
regulations. Since the objective is to ensure that the actual emissions
associated with facilities and MSCs operating under an approved plan do
not significantly exceed the emissions projected for that plan, BOEM
proposes to provide (as an option) a list of the kinds of emissions
sources that lessees and operators could monitor to satisfy the
requirements of this paragraph. On facilities, engine reporting and
monitoring would include and apply to: Onboard facility engines; power
generation engines; Hydraulic Power Units (HPU); deck cranes; cementing
units; and other engines with a maximum power rating exceeding 200 hp
(149 kW). On facilities, this list would exclude: propulsion engines,
boilers and incinerators, emergency generators, and lifeboat engines.
For MSCs, the emissions sources subject to measurement and reporting
could include: Propulsion engines; power generation engines; marine
auxiliary engines; and engines with a maximum power rating exceeding
200 hp (149 kW). On MSCs, this list would exclude boilers and
incinerators, emergency generators, all engines onboard science
vessels, offshore supply vessels, or lifeboats.
Further, measurement of actual emissions would be required to
reflect actual operations on the OCS and not exclusively on the basis
of ECEs, fuel

[[Page 19784]]

logs, or activity data. The lessee or operator would need to
demonstrate that the data submitted to BOEM under this section is
consistent with any data provided to BOEM under the requirements of
Sec. 550.187. The lessee or operator would be required to provide this
information in a manner and on a schedule determined by the Regional
Supervisor.
BOEM solicits comments as to how it should best implement the
requirements of this section with respect to those facilities that
would be required to report their actual emissions. BOEM invites
comments on this issue with respect to how best to achieve the
objective of obtaining actual data on potentially large pollution
emitters while not adversely impacting those small-volume emitters
whose emissions do not have any realistic potential to adversely affect
the air quality of any State.
Paragraph 550.311(c)--Notification Requirements
Proposed paragraph (c) would require the lessee or operator to
notify BOEM, if any of its actual emissions exceed its projected
emissions at any time after the plan has been approved and to provide
BOEM with the appropriate data regarding the exceedance.
If a lessee or operator proposes to make a change to the equipment
on its existing facility or facilities in a year or years when its plan
already anticipated operations, and its proposed change would result in
an increase in air pollutant emissions from that equipment for any air
pollutant, the lessee or operator would be required to submit a revised
plan, not simply a plan that describes the specific change being
proposed.
Paragraph 550.311(d)--Data Submittal Requirements
As with the reporting done pursuant to Sec. 550.205(d) of the
proposed section would specify that a lessee or operator must submit
data and information in a format, and using the forms, specified by
BOEM. The lessee or operator must submit information in an
electronically-readable format, unless otherwise directed by the
Regional Supervisor. If it transmits the information to BOEM
electronically, then it must use a delivery medium or transmission
method authorized by BOEM.
While the current regulation requires monitoring and reporting of
emissions, it does not specify what monitoring is required. The
proposed rule at Sec. 550.311 would provide more specificity on how
the monitoring and reporting must be carried out. BOEM believes a more
comprehensive approach to emissions measurement and monitoring could
improve the quality and type of information for estimating impacts on
affected States. BOEM requests comments and suggestions with respect to
the best approach to post-approval record-keeping, monitoring and
reporting, including potential alternative approaches.
Section 550.312--What post-approval recordkeeping and reporting is
required?
Paragraph 550.312(a)--Stack Testing
The proposed rule would include requirements necessary to validate
the emissions estimates that are described in a plan. The proposed rule
would specify at Sec. 550.312(a) if stack testing was used as a method
to develop emissions factors under proposed Sec. 550.205 or was used
to develop any other information submitted pursuant to that section,
then a lessee or operator would be required to conduct the stack
testing every three years and to report the results. BOEM seeks comment
on whether it should require or recommend that the stack testing data
be collected with the USEPA's electronic reporting tool and submitted
via CDX (Compliance and Emissions Data Reporting Interface-), so that
the USEPA can update the AP 42/WebFIRE emissions factors and so BOEM
can compile the relevant data and supply it to other lessees and
operators for their use in the future.
Paragraph 550.312(b)--Fuel Logs and Activity Data
Proposed Sec. 550.312(b) would describe the recordkeeping
requirements that would be necessary to demonstrate compliance with the
plan in all cases, whether or not ERM are required and whether or not
the conditions in proposed Sec. 550.311(a) were satisfied. Under the
proposed rule, lessees or operators would be required to retain
information on monthly fuel consumption, for each emissions source,
including attributed emissions sources, showing the quantity, type, and
sulphur content of fuel used; collect facility and equipment usage
information, including hours of operation at each percent of capacity
for each emissions source. Venting, flaring, flashing and any other
release of any air pollutant emissions that would not otherwise be
accounted for by fuel consumption would be required to be reported for
any emissions source that generates criteria air pollutants or
precursor air pollutants in connection with OCS activities.
The proposed rule would require the lessee or operator to retain
this information for a period of no less than 10 years. Reporting of
fuel logs, facility and equipment activity and usage information, and
fuel sulphur content must be provided to BOEM on a schedule established
by the Regional Director. This provision is intended to ensure ongoing
air quality compliance, after a plan is approved. It would both
maintain consistency with the USEPA's approach to regulating OCS
operations and retain the requirements of BOEM's current regulations at
30 CFR 550.303(k) and 550.304(g).
If BOEM elects to obtain the relevant data for a lessee's or
operator's attributed emissions from an independent third party, then
the Regional Supervisor may waive the requirement to submit fuel logs
or collect facility and equipment usage information for MSCs.
BOEM solicits comment on whether there are other ways of collecting
information or monitoring to ensure ongoing compliance with approved
plans. Additionally, BOEM requests comment on alternative approaches to
ensure compliance with an approved plan. BOEM also requests specific
comment on whether there are ways to minimize the data collection and
reporting burden associated with fuel logs while also ensuring the
ongoing compliance with an approved plan. For example, there may be
circumstances under which some facilities and/or MSCs would generate
such low levels of emissions that there would be no practical
possibility that the operations of those facilities and/or MSCs,
cumulatively or separately, could exceed any relevant EET(s). Under
those circumstances, the requirement to maintain fuel logs and/or
activity data records may not be necessary or could be modified. BOEM
solicits comment on what those circumstances may be and how BOEM might
craft an exception or modification to the record-keeping requirements
for small facilities and/or MSCs, so as to minimize the cost burden on
lessees and operators--consistent with BOEM's need to ensure the
integrity of its air quality regulatory program.
The proposed rule would also specify that record-keeping and
reporting must be consistent with the USEPA's requirements for
Electronic Reporting and Recordkeeping Requirements for New Source
Performance Standards. These are available in the following document:
Electronic Reporting and Recordkeeping Requirements for New Source
Performance Standards, 80 FR 15099, RIN 2060-AP63, March 20, 2015.

[[Page 19785]]

Paragraph 550.312(c)--Meteorological Reporting
The current Sec. 550.303(l) provides the Regional Supervisor may
require, for a period of time and in a manner approved or prescribed, a
lessee to collect and submit meteorological data from any of its
facilities. The proposed rule in Sec. 550.312(c) would include a
provision with similar language. However, the proposed rule would add a
provision allowing a lessee or operator to instead collect and report
meteorological data derived from any other mutually agreed upon
location with the approval of the Regional Supervisor.
Paragraph 550.312(d)--Other Information
The proposed rule in Sec. 550.312(d) would add a provision to make
clear the Regional Supervisor might require other information needed to
support any finding or determination under subpart C.
Paragraph 550.312(e)--Additional Requirements Imposed by Other Agencies
The proposed rule would clarify that another federal agency could
impose additional reporting, monitoring, or other requirements beyond
those proposed by BOEM. None of the provisions of this paragraph would
prevent the imposition of additional monitoring or reporting
requirements on the part of BSEE or any other federal agency.
Section 550.313--Under what circumstances will BOEM impose additional
requirements on facilities operating under already approved plans?
The proposed rule would provide that under certain circumstances
BOEM might impose additional requirements on existing facilities
operating under approved plans. In addition to the new requirement that
all plans be subject to a ten-year re-review process, the proposed rule
would provide that BOEM might impose other requirements on facilities
operating under an already approved plan if an applicable AAQSB changes
or if BOEM determines the operations are:

Causing or contributing to a violation of the NAAQS,
either individually or in combination with any other offshore
operations (this provision would also account for plans approved
with either a NOX or VOC waiver that may not continue to
be appropriate);
Emitting unauthorized air pollutants;
Creating conditions posing an unreasonable risk to
public health or welfare; or
Violating any applicable federal, State or tribal law
related to air quality.

Also if a plan approved as a short-term facility later becomes a
long-term facility, the proposed rule would require a lessee or
operator to submit an initial plan under the standards applicable to
long-term facilities. The proposed rule would allow the Regional
Director to grant a temporary exception to this requirement if the
short-term facility became a long-term facility as a result of adverse
weather conditions or other circumstances beyond the lessee's or
operator's control that delayed operations in the lease area. The
exception would not be allowed to exceed the number of months the
lessee or operator had been unable to operate.
Section 550.314--Under what circumstances will the Regional Supervisor
review the projected emissions from my existing facility or facilities?
The purpose of this proposed section is to outline the ongoing
requirements, which are intended to ensure the lessee or operator will
not allow its facility or facilities to generate emissions in excess of
those approved in the plan.
This section would update and modify the requirements in current
Sec. 550.304(a). That paragraph describes a process by which a State,
or a Federally-recognized Indian tribe having either a TAS status or a
USEPA-approved TIP, can request more information about emissions data
or the review of an existing plan. The proposed rule would provide that
a State or Indian tribe could request that the Regional Supervisor to
supply it with the air pollution data regarding an existing facility's
projected emissions, if such data were needed either for the updating
of the State's or Indian tribe's emissions inventory or because a State
or Indian tribe believed an existing facility's projected emissions
might cause or contribute to a violation of the NAAQS. The proposed
rule would further provide that lessees or operators might be required
to submit air pollutant emissions data to the entity submitting such a
request.
Further, under the proposed rule, the entity submitting a request
would be permitted to submit information to BOEM that it believed
indicated that projected emissions from an existing facility could
cause or contribute to a violation of the NAAQS. In such a case, the
lessee or operator responsible for the facility would be given the
opportunity to present information to the Regional Supervisor that
demonstrates its facility's projected emissions would not cause such an
effect. The Regional Supervisor would evaluate the new information
submitted and would determine whether the lessee or operator's actual
emissions, including their attributed emissions, would have the
potential to cause or contribute to a violation of the NAAQS. The
Regional Supervisor would base this determination on an evaluation of
the emissions data, the available meteorological data, and the distance
of the facility from the State or Reservation. If the Regional
Supervisor were to determine an existing facility's projected emissions
had the potential to cause or contribute to a violation of the NAAQS,
then the lessee or operator would be required to submit additional data
as requested by the Regional Supervisor. This provision is intended to
complement the provision described in Sec. 550.205(m), which outlines
those exceptional circumstances under which additional data or
information may be required.

D. 30 CFR Part 550, Subpart J

The following change is proposed in part 550, subpart J:
Section 550.1012--What are the air quality requirements for pipeline
rights-of-way holders?
Applications for rights-of-way are currently sent to and reviewed
by BSEE. The proposed rule would not change that process except to add
a requirement that any application for approval of a new pipeline ROW
would also be subject to BOEM's air quality requirements. The proposed
rule would specify that when a person applies for a right-of-way (ROW)
in any part of the OCS under the air quality regulatory jurisdiction of
the Department, its application would be required to include the
information required by Sec. 550.205 of this part and demonstrate that
the ROW complies with subpart C of this part. The proposed rule would
also specify that any requirement in either Sec. 550.205 or subpart C
that refers to plans should be interpreted to apply equally to rights-
of-way and that any requirement that refers to lessees should be
interpreted to apply equally to ROW holders or grantees.
There are a few exceptions proposed to these requirements that are
based on the unique nature of pipeline ROWs: The provisions in subpart
C that refer to the consolidation of multiple facilities and, the
periodic resubmittal of plans under proposed Sec. 550.310(c) would not
apply to ROW holders or grantees.

[[Page 19786]]

In addition, the proposed rule specifies that no additional
requirements would apply to a proposed or existing RUE that is already
included within the scope of an existing or proposed exploration or
development plan. The proposed rule would also specify that BOEM will
notify BSEE of its determination that the organization or individual
has provided the information required by Sec. 550.205 and met the
requirements of subpart C of this part. If necessary, BOEM would notify
BSEE of additional conditions necessary to ensure that the activities
will comply with subpart C of this part.

VI. Interagency and Public Outreach

The Department has and continues to make a substantial effort to
review its proposals with relevant stakeholders, both within and
outside the federal government. It has conferred, and intends to
continue to further confer, with the BSEE, the BLM, the FWS, the NPS,
the USEPA, the United States Coast Guard (USCG), the National Oceanic
and Atmospheric Administration and other relevant federal agencies
prior to formulating the final rule. BOEM also intends to review this
proposed rule with affected States.
DOI strives to strengthen its government-to-government relationship
with Federally-recognized Indian Tribes and Alaska Native Claims
Settlement Act Corporations through a commitment to consultation with
Indian Tribes and recognition of their right to self- governance and
Tribal sovereignty. This proposed rule will be subject to an extensive
public comment period and the views of all potentially affected
industry and interested environmental groups will be solicited and
carefully considered. The Department will consider and evaluate the
comments of all potentially affected and interested parties, consistent
with the OCSLA mandate that it appropriately balance the economic
benefits associated with ``expeditious and orderly development''
against the potential environmental risks (i.e., ``subject to
environmental safeguards'') that may be associated with any changes to
existing air quality regulations.

VII. Legal & Regulatory Analyses

A. Statutes

1. National Environmental Policy Act (NEPA) of 1969
BOEM has developed a draft Environmental Assessment (EA) to
determine whether this proposed rule would have a significant impact on
the quality of the human environment under the NEPA. The draft EA is
available for review and public comment in the docket for this proposed
rule at www.regulations.gov. Questions or comments related to the EA
should be directed to Eric Wolvovsky at 45600 Woodland Road, Sterling,
VA 20166; phone (703)787-1719; or email at Eric.Wolvovsky@boem.gov.
2. Paperwork Reduction Act (PRA) of 1995
This proposed rule contains a collection of information that has
been submitted to the OMB for review and approval under 44 U.S.C.
3507(d). If you wish to comment on the IC aspects of this proposed
rule, you may send your comments directly to OMB (see the ADDRESSES
section of this notice). Please reference 30 CFR part 550, subpart C,
Air Quality, 1010--NEW, in your comments. To see a copy of the IC
request submitted to OMB, go to https://www.reginfo.gov (select
Information Collection Review, Currently under Review); or you may
obtain a copy of the supporting statement for the new collection of
information by contacting the Bureau's Information Collection Clearance
Officer at (703) 787-1025.
The title of the collection for this rule is Air Quality, 30 CFR
part 550, subparts A, B, and C (Proposed Rulemaking).
This rulemaking proposes to add new IC requirements to current
regulations under 30 CFR part 550, subparts A, B, and C. The IC for the
current regulations has been approved under the following OMB Control
Numbers:

1010-0114 (subpart A), expires December 31, 2016
(30,635 hours; $165,492 non-hour costs).
1010-0151 (subpart B), expires January 31, 2018
(432,512 hours; $3,939,435 non-hour costs).
1010-0057 (subpart C), expires January 31, 2018
(112,111 hours; $0 non-hour costs).

This rule would add new and expand existing requirements under
regulations at 30 CFR part 550, subparts A and B, and would provide a
rewrite of 30 CFR part 550, subpart C. Therefore, we are requesting OMB
assign a new OMB Control Number for the IC requirements in the proposed
rule. When the final rule becomes effective, we will move the
requirements and burdens associated with subpart A and subpart B into
their respective collections. We will use the new OMB Control Number
for the IC requirements and burdens associated with the new subpart C
and will discontinue the use of current OMB Control Number 1010-0057.
The PRA provides 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 rule proposes: To incorporate the USEPA's regulatory standards
for air quality; address the expansion of BOEM's air quality
jurisdiction to include the OCS adjacent to the North Slope Borough of
the State of Alaska; account for technological advances in air quality
measurement, evaluation, and reporting capabilities; take into account
emissions from offshore supporting vessels; and reflect changes in
practices and procedures as they have evolved. Potential respondents
are holders and operators of federal OCS leases, operating rights
holders, holders of Rights of Use and Easement (RUEs), holders of
Pipeline Rights-of-Way (ROWs) or holders of a lease-term pipeline, and
independent third-parties working on behalf of any of these persons.
The frequency of response varies, but is primarily on the occasion or
as per the requirement. Responses to this collection are mandatory or
are required to obtain or retain a benefit. The IC does not include
questions of a sensitive nature. BOEM will protect proprietary
information according to the Freedom of Information Act (5 U.S.C. 552)
and DOI's implementing regulations (43 CFR part 2), 30 CFR part 552,
OCS Oil and Gas Information Program, and 30 CFR 550.197, Data and
information to be made available to the public or for limited
inspection.
We expect the estimated hour burden for the rulemaking to be
146,490 hours and $3,455,000 in non-hour costs. Some of the
requirements, especially in subpart A, are not new; they are being
moved or expanded. The table below provides a breakdown of the
estimates for the rule. Current OMB-approved hours and requirements are
in regular font; expanded requirements and hours are shown in italics.
The proposed new requirements are shown in bold and are summarized as
follows:

Subpart A. BOEM is proposing to implement a requirement
from the CAA to work with the USEPA to expand and maintain a
national air emissions inventory. The requirement to submit a copy
of a USEPA-required Episode Avoidance Plan is currently approved as
part of the IC in subpart C but would be collected under subpart A
(Sec. 550.141(d)) in the proposed rule. We expect no burden change
since the occurrence is very limited and therefore the burden
currently approved is sufficient. The proposed rule would expand a
requirement under right-of-use and easement (RUEs) to account for
air quality documentation and records (Sec. 550.160( f ) +287
hours). The rulemaking also proposes to codify details regarding the
gathering and reporting of OCS air inventory information, and
broaden the requirement from being applicable only to the Western
GOM to one that is applicable to all OCS regions. This requirement
and the

[[Page 19787]]

associated burdens are not new; they were originally accounted for
in subpart C, but have been modified and moved to subpart A. The
reasons for this are twofold. First, this requirement is unrelated
to the regulatory requirements involving the review of the potential
air quality impacts associated with proposed plans (i.e., the
primary purpose of subpart C). Second, the requirements for
collecting and maintaining air inventory information are meant to
apply to all owners and operators of facilities, including lessees,
lease operators, operating rights holders, holders of RUEs or
pipeline ROWs--whether or not that ROW includes an accessory
structure--and all owners and operators of non-stationary sources
operating on the OCS in support of any facility, whether or not such
person was required to submit or comply with the requirements of
subpart C (New Sec. 550.187, +112,425 hours). This would increase
the total burden under subpart A +112,712 hours.
Subpart B. To simplify the air quality review process,
BOEM is proposing to consolidate the requirements relating to air
quality into one new section (Sec. 550.205), which would be equally
applicable to all Exploration Plans (EPs), Development and
Production Plan (DPPs), or DOCDs, as well as to any updates or
modifications of any such plans. Proposed Sec. 550.205 includes the
expanded air quality emissions factors and reporting requirements
for all emissions sources. The proposed rule would expand BOEM's air
quality submission requirements to include any area in which BOEM is
given jurisdiction, including the OCS adjacent to the North Slope
Borough of the State of Alaska. To accommodate various changes in
the air quality requirements, BOEM will modify its current air
quality information forms (BOEM-0138, Air Emission Calculations for
EPs, and BOEM-0139, Air Emission Calculations for DPPs and DOCDs).
These forms will be updated to include the new air pollution
emissions factors and to reflect the addition of new emissions
sources and categories and types of equipment and vessels (e.g.,
icebreakers). The forms will be restructured to better accommodate
the consolidation of emissions across multiple, related facilities;
to better reflect the goal of complying with USEPA AAQSB; and to
reflect various other changes necessitated by the proposed
rulemaking. The forms will be renamed so that it is clear that they
are intended to be applicable and functional for all affected OCS
Regions. BOEM is working with a contractor to revise these forms to
provide automated calculations after data entry. The draft forms
will be included in the docket for this proposed rulemaking and will
be made available for public comment. The proposed modifications to
the forms will increase the current aggregated burdens for
submitting an EP, DOCD, and DPP by the following: for EPs, +3,100
hours; for DPP/DOCDs +5,150 hours. The proposed rule also expands
the current requirement to submit post-approval information for EP/
DPP/DOCD to include RUEs (Sec. 550.284 +224 hours). This would
increase the burden under subpart B +8,474 hours.
Subpart C. This rulemaking proposes a rewrite of
current subpart C regulations to address new air pollution
prevention and control requirements so we are addressing all
requirements as new. This subpart would require analysis and
modeling for expanded air emissions and compliance reporting for
those criteria and major precursor air pollutants that exceed the
threshold, and allow for air emissions consolidation from multiple
facilities (expanded from current regulations) (Sec. Sec. 550.303
and 550.304; 6,626 hours, $1,000,000 non-hour costs for modeling).
This subpart would also add the requirements associated with
emission reduction measures, including but not limited to the BACT
(Sec. Sec. 550.306 through 550.310; 682 hours), as well as
monitoring and reporting requirements, including the collection of
data and maintenance of fuel logs (Sec. Sec. 550.311 through
550.314; 17,986 hours, $2,455,000 non-hour costs); and general
departure information (Sec. Sec. 550.300 through 550.314; 10
hours). The proposed rule would create new subpart C with a total
burden of 25,304 hours and $3,455,000 non-hour costs.

Burden Table
[Current requirements in regular font; expanded requirements shown in italic font; new requirements shown in
bold font]
----------------------------------------------------------------------------------------------------------------
Reporting and
Citation 30 CFR part 550 subpart recordkeeping Hour burden Average number of Annual burden
A and related NTLs requirement ** annual responses hours
----------------------------------------------------------------------------------------------------------------
Per the requirements in this rule, you must submit information in an electronically readable format unless
otherwise directed by BOEM. If you transmit the information electronically, you must use a delivery medium or
transmission method authorized by BOEM
----------------------------------------------------------------------------------------------------------------
Information and Reporting Requirements
----------------------------------------------------------------------------------------------------------------
141(d)........................... Request approval to use Burdens currently covered under 30 0
new or alternative CFR part 550, subpart A (1010-0114)
procedures; temporarily
suspend equipment or
implement operational
control(s); submit
required information.
-------------------------------------
160(f)........................... Submit all air quality 11 26 applications.... 286
documentation/records
pertaining to RUE
applications; obtain
approvals.
160(f)........................... Request waiver of 10- .50 2.................. 1
year periodic review
for RUEs from Regional
Supervisor.
New 187*......................... Entities in all affected 43+ 2,547 submissions.. 112,025
OCS Regions collect,
maintain, retain for 10
yrs., and all air
emissions-related data
for each source that
generates air
pollutants on the OCS.
New 187(b)*...................... Request third-party 2 200 requests....... 400
submission of required
air emissions data to
BOEM or BOEM-designated
agent.
----------------------------------------------------
Total for Subpart A.......... ........................ .............. 2,775.............. 112,712
----------------------------------------------------------------------------------------------------------------

----------------------------------------------------------------------------------------------------------------
Reporting and
Citation 30 CFR 550 subpart B and recordkeeping Hour burden Average number of Annual burden
related NTL(s) requirement annual responses hours
----------------------------------------------------------------------------------------------------------------
Contents of Exploration Plans
----------------------------------------------------------------------------------------------------------------
200-206; 209; 215(e); 231(b); Submit amended, Burdens currently covered under 30 0
232(d); 234; 235; 281(d)(3); modified, revised, CFR 550, subpart B (1010-0151)
283; 284; 285; NTL 2010 N-06. supplemental, or
updated EP, or resubmit
disapproved EP;
withdraw an EP.
-------------------------------------

[[Page 19788]]

New 205.......................... Collect, maintain & 20 110 changed plans.. 2,200
submit all air quality
& modeling
documentation/records
(including but not
limited to, emissions
sources, factors,
reduction measures,
attributed and
projected emissions,
distance calculations,
etc.); additional
documentation as
requested/required by
BOEM; request
departures; obtain
approvals.
-------------------------------------
200-206; 209; 211 through 228; Submit EP and all Burdens currently covered under 30 0
NTL 2010-N-06. required information CFR part 550, subpart B (1010-0151)
(including, but not
limited to, submissions
required by BOEM forms
0137, 0138, 0142;
withdrawals; lease
stipulations; reports;
H2S; Geological and
Geophysical (G&G);
etc.); provide
notifications.
-------------------------------------
New 205.......................... Submit expanded air
emissions & compliance
data for EPs whose air
emissions are above the
exemption threshold.
Burdens for analysis/
modeling covered under
30 CFR part 550,
subpart C (Sec. Sec.
550.303-550.307).
Collect, maintain & 25 20 plans........... 500
submit all air quality
& modeling
documentation/records
(including but not
limited to, emissions
sources, factors,
reduction measures,
attributed and
projected emissions,
distance calculations,
etc.); additional
documentation as
requested/required by
BOEM; request
departures; obtain
approvals.
Alaska Region submits 200 2 Alaska plans..... 400
air quality information
as required in EP.
----------------------------------------------------
Subtotal..................... ........................ .............. 132................ 3,100
==================================
Contents of DPP and DOCD
----------------------------------------------------------------------------------------------------------------
Current 200-206; 209; 266(b); Submit amended, Burdens currently covered under 30 0
267(d); 272(a); 273; 281(d); modified, revised, CFR part 550, subpart B (1010-0151)
283(a-b); 284; 285(a-b); NTL updated, or
2010 N-06. supplemental DPP or
DOCD, or resubmit
disapproved DPP or DOCD.
-------------------------------------
New 205.......................... Collect, maintain & 20 155 changed plans.. 3,100
submit all air quality
& modeling
documentation/records
(including but not
limited to, emissions
sources, factors,
reduction measures,
attributed and
projected emissions,
distance calculations,
etc.); additional
documentation as
requested/required by
BOEM; request
departures; obtain
approvals.
-------------------------------------
200-206; 209; 241 thru 262; NTL Submit DPP/DOCD and Burdens currently covered under 30 0
2010 N-06, and others. accompanying/supporting CFR part 550, subpart B (1010-
information (including, 0151).
but not limited to,
submissions required by
BOEM Forms 0137, 0139,
0142 used in GOM; lease
stipulations;
withdrawals, etc.);
provide notifications.
-------------------------------------
New 205.......................... Submit expanded air 25 50 plans........... 1,250
emissions & compliance
data for DPPs/DOCDs
whose air emissions are
above the exemption
threshold. Burdens for
analysis/modeling
covered under 30 CFR
part 550, subpart C
(Sec. Sec. 550.303-
550.307).
Collect, maintain &
submit all air quality
& modeling
documentation/records
(including but not
limited to, emissions
sources, factors,
reduction measures,
attributed and
projected emissions,
distance calculations,
etc.); additional
documentation as
requested/required by
BOEM; request
departures; obtain
approvals.
Alaska Region submits 400 2 Alaska plans..... 800
air quality information
as required in DPP/DOCD.
284.............................. Submit updated 4 56 updates......... 224
information on
activities conducted
under approved EPP/DPP/
DOCD/RUE.
----------------------------------------------------
Subtotal..................... ........................ .............. 263................ 5,374
----------------------------------------------------

[[Page 19789]]

Total Subpart B.......... ........................ .............. 395................ 8,474
----------------------------------------------------------------------------------------------------------------

----------------------------------------------------------------------------------------------------------------
Non-hour costs
Citation 30 CFR 550 subpart C Reporting and ----------------------------------------------------
and related NTL(s) recordkeeping Average number of Annual burden
requirement Hour burden annual responses hours
----------------------------------------------------------------------------------------------------------------
Air Quality Analyses in Plans
----------------------------------------------------------------------------------------------------------------
New 303-307...................... Conduct required 38 87 plans........... 3,306
analysis & modeling for
expanded air emissions
for those criteria &
major precursor air
pollutants that exceed
the threshold &
compliance
requirements. Submit
modeling reports.
-------------------------------------
$10,000 x 20 instances for $1,000,000
incremental modeling/analysis cost
of mobile sources = $200,000
$20,000 x 40 instances for
additional plans that will now
require modeling/analysis =
$800,000
$50,000 x 0 instances for plans now
requiring photochemical modeling/
analysis = no costs till 2020
----------------------------------------------------------------------------------------------------------------
New 303(d)....................... Report/consolidate air 20 15 consolidations.. 300
emissions data from
multiple facilities if
required.
-------------------------------------
New 303(g); 310(c); 312(b)....... Submit revised air Burdens currently covered under 30 0
emissions plans, as CFR part 550, subpart B (1010-
required. Request 0151).
exceptions; obtain
approvals.
-------------------------------------
New 303(h)....................... Provide additional 10 300 submissions.... 3,000
information/analysis as
required for plan
approval.
New 304.......................... Obtain approval of all 5 4 submissions...... 20
modeling protocols &
meteorological data
sets. Provide BOEM with
copies of/access to
protocols & all
required information.
----------------------------------------------------
Subtotal..................... ........................ .............. 406................ 6,626
------------------------------------
.............. $1,000,000 Non-hour Costs
----------------------------------------------------------------------------------------------------------------
Emission Reduction Measures--BACT
----------------------------------------------------------------------------------------------------------------
New 306; 307; 308(a); 309(a), Document results of ERM 50 12 submissions..... 600
(c), (d). analysis. Provide
description of BACT
proposal/data based on
required analyses,
associated impacts and
costs; demonstrating
compliance; provide
additional information
as required; obtain
approval; Submit ECE
data from manufacture.
New 307(a); 313(a)............... Request VOCs or NOX 1 1.................. 1
waiver for ERM.
-------------------------------------
New 308(b); 309(a)............... Request reconsideration Not considered IC as defined in 5 0
of BOEM emissions CFR 1320.4(a)(2).
determination; submit
supporting information.
-------------------------------------
New 309(b)....................... Immediately notify BOEM 2 2 notifications.... 4
if ERM become disabled
or unavailable; request
extension for ERM (NTE
90 days).
New 309(d)....................... Collect and maintain 12/yr. 6.................. 72
monthly logs of
relevant meter/
monitoring equipment
readings.
New 309(e)....................... Notify appropriate State 1 1 notification..... 1
air quality control
jurisdiction of
proposal to acquire
emissions offsets;
revise State
Implementation Plan to
include new info;
submit to BOEM.
New 310(b)....................... Request a departure from 2 2 requests......... 4
compliance with the new
or revised AAQSB.
-------------------------------------
New 310(c)....................... Resubmit plans for air There will be no burden until 2020 0
quality review every 10
years w/required
information.
-------------------------------------
Subtotal..................... ........................ .............. 24................. 682
----------------------------------------------------------------------------------------------------------------

[[Page 19790]]

Monitoring & Reporting
----------------------------------------------------------------------------------------------------------------
New 311(a), (b), (f)............. Report/demonstrate 16 12 submissions..... 192
actual emissions data/
other information to
verify compliance with
previous approved plan
on BOEM approved
schedule.
New 311(c)....................... Measure actual emissions 36 30 engines......... 1,080
using Predictive
Emission Monitoring
System (PEMS).
----------------------------------------------------
$26,000 x 30 engines = 780,000 annually
----------------------------------------------------
New 311(c)....................... Report data/information 16 5.................. 80
regarding exceedance of
projected emissions to
BOEM.
New 312(b), (d);................. Submit additional 2 10 submissions..... 20
information as required
to BOEM.
New 312(a)....................... Conduct/report stack 48 67 tests........... 3,216
testing results every 3
yrs.
----------------------------------------------------
$25,000 x 67 stack tests = $1,675,000 annually
----------------------------------------------------
New 312(b)....................... Retain monthly fuel 48 265................ 12,720
information for each
source on determined
schedule for 10 yrs.
New 312(b)....................... Submit fuel logs or 8 80................. 640
collect facility and
equipment usage
information for MSCs to
BOEM.
New 312(c), (d).................. Collect/report 4 3.................. 12
meteorological data in
a manner described by
BOEM or from agreed
location; other
information as required.
New 313(b)....................... Submit new air quality 10 2 submissions...... 20
plan for short-term
facility converted to a
long-term facility.
New 313(b)....................... Request exception due to .50 4.................. 2
adverse weather
conditions or
circumstances beyond
your control.
New 314.......................... Provide pollution data 2 2 requests......... 4
to State, Indian Tribe,
or federal agency
requests submit
additional info. for
determination to any
cause/contribution to
NAAQS violation within
120 days or a longer
time specified by BOEM.
----------------------------------------------------
Subtotal..................... 480................ 17,986
------------------------------------
........................ .............. $2,455,000 Non-hour Costs
----------------------------------------------------------------------------------------------------------------
General
----------------------------------------------------------------------------------------------------------------
New 300-314...................... General departure and 2 5 requests......... 10
alternative compliance/
requests not
specifically covered
elsewhere in subpart C.
----------------------------------------------------------------------------------------------------------------
Subtotal..................... ........................ .............. 5.................. 10
----------------------------------------------------
Total for Subpart C...... ........................ .............. 915................ 25,304
------------------------------------
.............. $3,455,000 Non-Hour Costs
----------------------------------------------------------------------------------------------------------------

----------------------------------------------------------------------------------------------------------------
Reporting and
Citation 30 CFR 550 subpart J and recordkeeping Hour burden Average number of Annual burden
related requirement annual responses hours
----------------------------------------------------------------------------------------------------------------
1012............................. Collect, maintain & Burden covered under 30 CFR part 0
submit all air quality 550, subparts B and C.
documentation/records
pertaining to pipeline
ROW applications;
obtain approvals..
----------------------------------------------------
Total Burden................. ........................ .............. 4,085.............. 146,490
----------------------------------------------------
.............. $3,455,000 Non-Hour Costs
----------------------------------------------------------------------------------------------------------------
* The requirements and burdens added to 30 CFR part 550, subpart A, are not entirely new; they are in current 30
CFR part 550, subpart C. This rulemaking moves those requirements to subpart A.
** In the future, BOEM will be allowing the option of electronic reporting for certain requirements.
+ Exact numbers of responses and annual burden hours were approved by OMB January 2015; numbers are from ROCIS.

BOEM uses the information collected under subparts A, B, and C to
ensure operations on the OCS are carried out in a safe and
environmentally sound manner, do not interfere with the rights of other
users, and balance the protection and development of OCS resources.

[[Page 19791]]

As part of our continuing effort to reduce paperwork and respondent
burdens, we invite the public and other federal agencies to comment on
any aspect of the reporting and recordkeeping burden. We specifically
solicit comments on the following questions:
(1) Is the proposed collection of information necessary for BOEM to
properly perform its functions, and will it be useful?
(2) Are the estimates of the burden hours of the proposed
collection reasonable?
(3) Do you have any suggestions that would enhance the quality,
clarity, or usefulness of the information to be collected?
(4) Is there a way to minimize the IC burden on those who must
respond, including the use of appropriate automated electronic,
mechanical, or other forms of information technology?
In addition, the PRA requires agencies to estimate the total annual
reporting and recordkeeping non-hour cost burden resulting from the
collection of information, and we solicit your comments on this item.
For reporting and recordkeeping only, your response should split the
cost estimate into two components: (1) Total capital and startup cost
component; and, (2) annual operation, maintenance, and purchase of
services component. Your estimates should consider the costs to
generate, maintain, and disclose or provide the information. You should
describe the methods you use to estimate major cost factors, including
system and technology acquisition, expected useful life of capital
equipment, discount rate(s), and the period over which you incur costs.
Generally, your estimates should not include equipment or services
purchased (1) before October 1, 1995; (2) to comply with requirements
not associated with the IC; (3) for reasons other than to provide
information or keep records for the Government; or (4) as part of
customary and usual business or private practices.
OMB is required to make a decision concerning the collection of
information contained in these proposed regulations between 30 to 60
days after publication of this document in the Federal Register.
Therefore, a comment to OMB is best assured of having its full effect
if OMB receives it by May 5, 2016. This does not affect the deadline
for the public to comment to BOEM on the proposed regulations. If you
wish to comment on the IC aspects of this proposed rule, you may send
your comments by email directly to OMB (OIRA_submission@omb.eop.gov) or
by fax 202-395-5806, with a copy to BOEM (see the ADDRESSES section).
Please reference Air Quality, 30 CFR part 550, subparts A, B, and C
(Proposed Rulemaking) in your comments. To see a copy of the IC
request, with the draft proposed forms, submitted to OMB, go to https://www.reginfo.gov (select Information Collection Review, Currently under
Review). You may also obtain a copy of the supporting statement and
draft forms for the new collection of information by contacting Nicole
Mason, the Bureau's Information Collection Clearance Officer, by mail
at 45600 Woodland Rd., Sterling, VA 20166, by email at
Nicole.Mason@boem.gov, or by phone at (703) 787-1025.
3. Regulatory Flexibility Act and Small Business Regulatory Enforcement
Fairness Act of 1996
The Regulatory Flexibility Act, 5 U.S.C. 601-612, requires agencies
to analyze the economic impact of proposed regulations when a
significant economic impact on a substantial number of small entities
is likely and to consider regulatory alternatives that will achieve the
agency's goals while minimizing the burden on small entities. In
addition, the Small Business Regulatory Enforcement Fairness Act of
1996, 5 U.S.C. 601 note, requires agencies to produce compliance
guidance for small entities if the rule has a significant economic
impact. For the reasons explained in this section, BOEM has concluded
that the proposed rule would likely not have a significant economic
impact on a substantial number of small entities and, therefore, a
regulatory flexibility analysis is not required. This Initial
Regulatory Flexibility Analysis (IRFA) assesses the impact of the
proposed rule on small entities, as defined by the applicable Small
Business Administration (SBA) size standards. The IRFA can be found in
the Initial Regulatory Impact Analysis (IRIA) within the docket for
this rulemaking. The IRFA assesses the impact of the proposed rule on
small entities, as defined by the applicable SBA size standards.
Based on this initial analysis, BOEM expects the implementation of
this proposed rule may have a significant economic impact on a
substantial number of small entities under 5 U.S.C. 605(b). BOEM,
however, is seeking comments on the IRIA to inform its analysis and
conclusions regarding the degree to which this rule may have an
economic impact on such entities.
As defined by the SBA, a small entity is one that is
``independently owned and operated and which is not dominant in its
field of operation.'' The definition of small business varies from
industry to industry in order to properly reflect industry size
differences. The proposed rule would affect operators and holders of
BOEM-issued oil and gas leases that are seeking to explore, develop or
transport OCS oil and gas resources. BOEM's analysis shows that this
could include about 130 companies with active operations. Entities that
operate under this rule fall under the SBA''s North American Industry
Classification System codes 211111 (Crude Petroleum and Natural Gas
Extraction) and 213111 (Drilling Oil and Gas Wells) or 237120 (Oil and
Gas Pipeline and Related Structures). For these codes, a small company
is defined as one with fewer than 500 employees. A small entity is one
that is ``independently owned and operated and which is not dominant in
its field of operation.'' Based on this criterion, approximately 90 (69
percent) of the 130 companies operating on the OCS are considered small
and the remaining are considered large businesses.
Of the approximately 130 operators, a total of 56 companies
submitted initial, revised, or supplemental exploration/development
plans during calendar year 2013. Twenty-four large companies submitted
63 percent of the plans and thirty-two small companies submitted 37
percent of the plans. Operators not submitting exploration or
development plans typically are continuing existing operations or hold
leases undergoing geological and geophysical exploration.
Submitting an exploration or development plan is a necessary step
before companies explore for hydrocarbons on the OCS or develop an
economic prospect. All companies operating on the OCS including small
entities must be well capitalized to undertake these multi-million or
multi-billion dollar projects. The incremental cost for providing
additional or consolidated air quality information for exploration
plans, DOCDs or DPPs, ROWs or RUEs is a small cost in the context of an
exploration or development project. Most of the compliance costs
imposed as a result of this rulemaking are variable costs directly
dependent on the complexity and number of plans submitted. Emission
reduction measure costs would be directly related to the impact a
project may have on a State's air quality. BOEM's first-order estimate
for the rulemaking's small entity compliance costs is proportional to
the number of plans submitted excluding ERM costs.
The compliance costs from this rulemaking may be less for most
small

[[Page 19792]]

entities because these companies are less likely to operate the large
projects that employ multiple MODUs drilling concurrently. If a
facility or project is located close to the federal/State submerged
lands boundary, shows emissions above the SILs in a non-attainment area
and is operated or owned by a small entity, this proposed rule could
have an economic impact. The GOM shelf is a mature hydrocarbon
environment and few companies are initiating new exploration or
development projects. However, the GOM shelf is where most of the small
entities operate and hold leases. While most of the compliance costs
would be imposed on lessees and operators of large deepwater projects,
some near-shore projects may be impacted.
Using 2013 as a base, small companies submit about 37 percent of
the plans each year and are expected to incur approximately the same
proportion of costs. The incremental first year compliance costs for
this rulemaking are projected to be $23 million and the peak year is
$49 million. Some of those costs are for ERM or emissions credits on a
very small number of projects which may or may not be owned or operated
by small entities. The modeling, reporting and other costs range from
$7 to $28 million each year and small entities operating in the GOM are
estimated to incur a similar proportion (37 percent) of costs in each
subsequent year. As described in more detail in the Executive Summary
to the Regulatory Impact Analysis (RIA), these costs are expected to
vary from approximately $3 million in the first year up to $10 million
in the 10th year.
BOEM prepared an IRFA to assess the impact of the proposed rule on
small entities, as defined by the applicable SBA size standards. The
IRFA is prepared using conservative assumptions and seeks public
comments on potential small entity impacts. This rule would only affect
operators and federal oil and gas lessees that could conduct operations
on the OCS. The Regulatory Flexibility Act, 5 U.S.C. 601-612, defines
small entities as small businesses, small nonprofits, and small
governmental jurisdictions. We have identified no small nonprofits or
small governmental jurisdictions that the rule would impact.
For the reasons explained below, BOEM has concluded this rule will
not have a significant economic impact on a substantial number of small
entities and that, therefore, a regulatory flexibility analysis is not
required.
This incremental modeling and reporting costs for this rulemaking
will generally be required of both the larger deepwater projects and
near-shore projects. While there are smaller companies that explore and
operate in deeper water, these companies are well capitalized and the
incremental compliance costs for this rulemaking are estimated to be
minimal when compared to the cost of drilling a single deepwater well.
Although BOEM does not believe that the proposed rule would have a
significant economic impact on a substantial number of small entities,
BOEM is requesting comment on the costs and impacts of the proposed
policies in this rule on small entities. We will consider all comments
at the final rule stage. We specifically request comments on the
compliance cost estimates as well as regulatory alternatives that would
reduce the burden on small entities.
This proposed rule:
a. Would not have an annual effect on the economy of $100 million
or more. The compliance cost will not materially affect the economy
nationally or in any local area.
b. Would not cause a major increase in costs or prices for
consumers; individual industries; federal, State, tribal or local
government agencies; or geographic regions. This proposed rule would
have minimal effects on OCS operators and is not anticipated to impact
oil and gas production or the cost of fuels for consumers.
c. Would 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. This
rule would have a negligible economic effect on the OCS oil and gas
industry. BOEM has determined that the current costs of implementation
of the current USEPA standards would likely not be significant, and
that any costs associated with potential future USEPA actions are too
speculative for purposes of analysis.
Pursuant to section 213(a) of the Small Business Regulatory
Enforcement Fairness Act of 1996 (Pub. L. 104-121), we want to assist
small entities in understanding this proposed rule so they can better
evaluate its effects on them and participate in the rulemaking. If you
believe this rule would affect your small business, organization, or
governmental jurisdiction and you have questions concerning its
provisions or options for compliance, you may contact Peter Meffert,
Bureau of Ocean Energy Management Office of Policy, Regulation, and
Analysis at Peter.Meffert@boem.gov or mail to 45600 Woodland Road,
Sterling, Virginia 20166; or call (703)787-1610.
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 to the Regional Small Business Regulatory
Fairness Board. 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 BOEM, call 1-888-REG-FAIR (1-888-
734-3247).
4. Unfunded Mandates Reform Act of 1995
This rule does not impose on State, local, or tribal governments,
or the private sector an unfunded mandate 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 Unfunded Mandates Reform Act
(2 U.S.C. 1531 et seq.) is not required.

B. Executive Orders (E.O.) and Presidential Memorandum

1. Governmental Actions and Interference With Constitutionally
Protected Property Rights (E.O. 12630) March 15, 1988
According to E.O. 12630, this proposed rule does not have
significant takings implications. The rulemaking is not a governmental
action capable of interfering with constitutionally protected property
rights. A Takings Implication Assessment is not required.
2. Regulatory Planning and Review (E.O. 12866) October 4, 1993
The OMB has reviewed this rulemaking under section 6(a)(3) of E.O.
12866. OMB has determined this proposed rule is significant because it
will potentially raise novel legal or policy issues. This rulemaking is
not economically significant.
Executive Order 12866 provides the Office of Information and
Regulatory Affairs (OIRA) within OMB will review all significant rules.
To the extent permitted by law, each agency must, among other things:
(a) Propose or adopt a regulation only upon a reasoned determination
that its benefits justify its costs (recognizing some benefits and
costs are difficult to quantify); (b) tailor its regulations to impose
the least burden on society, consistent with attaining regulatory
objectives, taking into account, among other things, and to

[[Page 19793]]

the extent practicable, the costs of cumulative regulations; (c)
select, in choosing among alternative regulatory approaches, those
approaches that maximize net benefits (including potential economic,
environmental, public health and safety, and other advantages;
distributive benefits; and equity); (d) to the extent feasible, specify
performance objectives, rather than specifying the behavior or manner
of compliance that regulated entities must adopt; and (e) identify and
assess available alternatives to direct regulation, including providing
economic incentives to encourage the desired behavior, such as user
fees or marketable permits, or providing information with which choices
can be made by the public.
(1) The proposed requirements in this rule would not have an effect
of $100 million or more per year on the economy. The proposed rule
would alter requirements for reporting emissions in an operator's
exploration or development plan. The proposed rule also would require
more accurate estimating and reporting of the emissions associated with
offshore operations. The compliance costs for this rulemaking primarily
relate to air dispersion and photochemical grid modeling, air pollutant
emissions monitoring, air quality monitoring and the implementation of
emission reduction measures (including the use of emissions credits).
The remaining compliance costs are for additional paperwork burden
hours identified in the section of the preamble on the PRA for
Operators submitting EPs and DOCDs or DPP pipeline Rights-of-Way ROW,
RUE and lease term pipeline applications. BOEM estimates the industry
compliance costs for activities in the first year will be $23 million,
the peak year (2020) $49 million and $290 million over 10 years
discounted at 3 percent. The government staffing costs are estimated to
be about $1.6 million per year and $12 million over 10 years discounted
at 3 percent. BOEM estimates the total first year compliance cost for
both the regulated industry and the government is $23.6 million, $51
million for the peak year and over 10 years is $302 million discounted
at 3 percent. Additional information on the compliance costs can be
found in the rulemaking's draft RIA posted in the docket.
The qualitative benefits for the proposed regulatory changes would
be the improved ability to ensure the continued development of offshore
facilities does not adversely impact any State, including its human
population, economy and environment, as well as the improved
information BOEM and States will receive regarding the expected air
quality impacts onshore and above State submerged lands from OCS
exploration and development. The proposed regulatory changes will
require more accurate emissions information resulting from BOEM-
authorized operations in both the Arctic and GOM. This improved air
emission information will better ensure BOEM only approves plans that
meet the requirements of the OCSLA (43 U.S.C. 1331 et seq., Pub. L. 83-
212, as amended), to ensure compliance with the NAAQS to the extent
that these operations do not significantly affect the air quality of
any State. The proposed rule would strengthen the requirements for
identifying, modeling, measuring and tracking the emissions of air
pollutants. Coastal States and other stakeholders can thereby be more
confident regarding the expected onshore air quality impacts from OCS
oil and gas exploration and development. The additional monitoring
information required for certain plans will also permit the BSEE to
better assess the air quality compliance for OCS operations on a plan-
by-plan basis.
Based on a consideration of the qualitative as well as quantitative
factors related to the rulemaking proposal, BOEM's assessment is that
it is necessary to achieve compliance with the requirements of the
OCSLA and that the proposed rule's adoption would provide a net benefit
to the public. The additional monitoring information required for
certain plans will also permit the BSEE to better assess the air
quality compliance for OCS operations on a plan-by-plan basis.
The table below summarizes BOEM's estimate of the 10-year
quantifiable net benefits. BOEM has only estimated the quantified
benefits of NOX reductions. The greatest compliance cost and
NOX reduction benefits are expected for deepwater projects,
especially in the Mississippi Canyon area. The quantifiable benefits
are estimated to range from $8 million to $43 million per year and are
attributed to the NOX reductions due to ERMs or emissions
credits on those few projects that are expected to require emission
reductions. The bureau's analysis did not quantify other benefits that
are too difficult to estimate in concrete fiscal terms. Additional
information on the compliance costs and benefits can be found in the
IRIA. Even though the quantified net benefits are negative in most
years, these benefits do not reflect the full implications of the
impact that the rule will have overall. First, the rule could result in
the reduction of VOCs, SOX, CO, and PM emissions if
operational controls are required as a condition of BOEM plan approval
that would not otherwise be employed by operators. These potential
reductions have not been quantified because BOEM believes most
operators will voluntarily utilize operational controls including best
combustion practices due to fuel savings. Second, the rule could result
in a lower rate of O3 and PM formation onshore than those
which have been quantified because there are likely to be reductions in
O3 and PM formation rates associated with non-NOX
reductions in precursor air emissions.\92\ Third, the rule is necessary
in order to ensure continued compliance with the mandates of OCSLA and,
as such, is essential to the continued development of oil and gas
resources on the OCS. Fourth, the elimination of the mandate to use
BACT as an emissions control will allow lessees and operators to
utilize offsets whenever they are cheaper. This unquantified benefit
would directly reduce the compliance costs of this rule, as compared to
the current regulations. Finally BOEM believes the other qualitative
benefits referred to in the RIA, such as the potential reduction in
compliance costs \93\ associated with this rulemaking and the superior
environmental effects of implementing offsets onshore rather than
offshore, will be more than sufficient to provide on overall positive
benefit and justification for this rulemaking.
---------------------------------------------------------------------------

\92\ In addition to reductions in the rate of O3 formation
resulting from NOX emissions reductions, there could also
be reductions in the rate of O3 formation by unquantified reductions
in VOCs. In addition, there could be additional reductions in the
rate of PM formation that are due to unquantified reductions in non-
NOX PM precursors.
\93\ Examples of this include, the ability to substitute offsets
for BACT in cases where the offsets would be more cost effective and
allowing offsets to be established onshore, where they are likely to
be less expensive and more environmentally beneficial, rather than
offshore.

[[Page 19794]]

Estimated AD82 Annualized Rulemaking Net Benefits
--------------------------------------------------------------------------------------------------------------------------------------------------------
Millions $, years
-----------------------------------------------------------------------------------------------------------------------
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
--------------------------------------------------------------------------------------------------------------------------------------------------------
Estimated Industry Compliance $22.9 $29.9 $35.9 $49.4 $45.1 $36.6 $31.5 $31.7 $27.7 $28.4
Costs..........................
Estimated Benefit (NOX $26.5 $35.3 $43.1 $43.1 $34.3 $18.6 $8.8 $7.8 $0.0 $0.0
Reductions)....................
-----------------------------------------------------------------------------------------------------------------------
Estimated Net Benefit....... $3.5 $5.4 $7.2 -$6.3 -$10.8 - $18.0 -$22.7 -$23.9 -$27.7 -$28.4
--------------------------------------------------------------------------------------------------------------------------------------------------------

BOEM does not expect that the proposed regulatory changes will be
unduly burdensome to industry. The proposed requirements are intended
to improve BOEM's review and approval of planned operations by
requiring more accurate information and better assessments of the air
quality impacts from OCS oil and gas operations. While many of the
proposed regulatory changes require additional information from
operators, the changes are not expected to increase the incidences of
mechanical BACT on OCS facilities. BOEM expects that plans usually will
employ ERMs and emissions credits as a response to failing to meet
exemption thresholds. Mechanical BACT emission controls or other ERMs
may be required for some projects due to the proposed requirements in
this rulemaking if emissions credits are not available. Other
exploration or development projects may require ERMs due to changes in
the USEPA 1-hour NOX standard \94\ or changes to the
O3 standard.
---------------------------------------------------------------------------

\94\ USEPA has issued guidance recommending a SIL for the 1-hour
NO2 NAAQS, which it published at: https://www3.epa.gov/nsr/documents/20100629no2guidance.pdf.
---------------------------------------------------------------------------

(2) The proposed rule would not adversely affect in a material way
the economy, productivity, competition, jobs, the environment, public
health or safety, or State, local, or tribal governments or
communities. The changes proposed in this rule would strengthen the
environmental safeguards and provide additional information to BOEM and
coastal States to assess potential impacts to air quality. As discussed
in the E.O. 13175 Consultation and Coordination with Indian Tribal
Governments section of this preamble, BOEM will hold consultation
meetings in Alaska.
(3) This proposed rule would not create a serious inconsistency or
otherwise interfere with an action taken or planned by another agency.
BOEM has consulted with the BLM, FWS, NPS, the Forest Service of the
Department of Agriculture, and the USEPA and has proposed changes to
align its regulations with those of the BLM, FWS, the NPS and the USEPA
where applicable. While the proposed rule would allow the use of the
MARPOL emissions standards as proxies for marine diesel engine emission
factors for marine engines, the USCG and the USEPA will continue to
enforce any applicable emissions limits on vessels. The proposed
regulatory changes would improve the information available and
facilitate BLM, FWS and NPS analysis regarding the air quality impacts
on Class II areas and endangered species.
(4) This proposed rule would not alter the budgetary effects of
entitlements, grants, user fees, or loan programs or the rights or
obligations of their recipients.
(5) This proposed rule potentially raises novel legal or policy
issues regarding consistency with other federal agencies or
international vessel requirements. The novel legal and policy issues
are the change in attributed emissions for plans as well as the
proposed relocation of the compliance boundary from the shoreline to
the offshore submerged lands (State seaward) boundary used for
determining exemptions from more detailed air quality analysis and/or
modeled compliance with NAAQS. This proposed rule formalizes the
methodology for attributed emissions. The 25-mile radius traditionally
used by BOEM will no longer apply; the projected emissions calculations
account for all emissions supporting a plan's activity, including in
certain cases support emissions from aircraft and onshore facilities.
BOEM has linked its air quality regulations, where applicable, to
those of other agencies in multiple areas. Many USEPA standards have
been explicitly cited and referenced. The Marine Pollution Convention
(MARPOL) standards, which are covered in USEPA and USCG regulations,
are incorporated. The BLM, FWS, NPS, and the Forest Service of the
Department of Agriculture programs to maintain AQRVs, as part of the
FLM process, have been explicitly referenced in the BOEM regulations.
In addition, informal consultations have and will continue to take
place with other federal and State agencies.
We have developed this proposed rule consistently with these
requirements. The proposed changes in this rulemaking would update and
better conform BOEM's air quality regulations to the requirements of
OCSLA. The proposed air quality requirements would automatically be
updated as the USEPA changes its standards with respect to which
pollutants are potentially harmful and at what levels of exposure those
pollutants cause harm. The proposed rule would replace various
provisions in the current regulations with more comprehensive and up-
to-date provisions based upon more recent science and technology. The
rulemaking would better address DOI's mandate to evaluate the potential
impact of any OCS development with respect to the probable impacts to
most closely affected States.
3. Civil Justice Reform (E.O. 12988) February 7, 1996
This proposed rule complies with the requirements of E.O. 12988.
Specifically, this proposed rule:
(a) Meets the criteria of section 3(a) requiring 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.
4. Protection of Children From Environmental Health and Safety Risks
(E.O. 13045) April 21, 1997
We have analyzed this proposed rule under E.O. 13045, Protection of
Children from Environmental Health Risks and Safety Risks. The USEPA
has determined, and BOEM agrees, that children are an at-risk group for
health effects associated with exposures to certain air pollutants,
including some pollutants released or formed from OCS operations.
This proposed rule addresses those air pollutants of greatest
concern. BOEM welcomes additional comments on this topic and whether,
or to what extent, the proposed rule addresses these relevant issues.

[[Page 19795]]

This proposed rule is not an economically significant rule and does
not create an environmental risk to health or a risk to safety that may
disproportionately affect children.
5. Federalism (E.O. 13132) August 10, 1999
Under the criteria in E.O. 13132, this proposed rule would not have
any substantial federalism implications. This proposed rule would not
substantially and directly affect the relationship between the federal
and State governments. To the extent that State and local governments
have a role in OCS activities, this proposed rule would not have any
significant effect on that role.
A separate federalism assessment is not required and has not been
prepared.
6. Consultation and Coordination With Indian Tribal Governments (E.O.
13175) November 6, 2000
DOI 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. BOEM has evaluated this proposed rule under the
Department's consultation policy and under the criteria in Executive
Order 13175 and has determined this proposed rule would not cause a
substantial direct or adverse effect on any Federally-recognized Indian
tribe.
There are a number of reasons why BOEM has come to this conclusion.
There are many circumstances whereby the proposed rule has strengthened
the requirements for identifying, measuring and tracking the emissions
of air pollutants and no circumstances in which the proposed rule would
relax or lessen any existing air quality requirements or standards. The
proposed rule would incorporate the various enhancements to the current
BOEM air quality regulatory process, including but not limited to the
following:

The proposed rule would incorporate all key USEPA air
quality standards and benchmarks by direct cross-reference. Thus,
BOEM's proposed regulations would both reflect current USEPA
standards and would be updated automatically in the future if a new
air quality standard or benchmark were to be promulgated by the
USEPA.
The proposed rule expands the circumstances under which
emissions from MSCs would be accounted for in both exploration and
development plans. MSC emissions would be tracked and reported
whenever a vessel would be operating in support of a regulated
facility, regardless of its distance from that facility.

The proposed rule would enhance the accuracy of the evaluation of
emissions from support vessels by measuring all such emissions from the
point at which they occur. The proposed rule mandates all potentially
significant emitters of air pollutants maintain fuel logs, which can be
used to calculate their potential emissions. This proposed rule
contains new provisions for mandatory stack testing or the installation
of meters when the Regional Supervisor determines emissions estimates
may be unreliable or inaccurate. In circumstances where a lessee or
operator proposes to use equipment that is not compliant with the USEPA
requirements, the proposed rule would require the lessee or operator to
obtain relevant air pollutant emissions data from the equipment
manufacturer or, alternately, to test the actual level of pollutants
that are emitted.
The proposed rule does reflect changes Congress made with respect
to the CAA when it granted Federally-recognized Indian tribes the right
to regulate the air quality over their territories independently from
the States. If such a tribe has been granted the authority to regulate
its own air quality, by issuing air quality permits in lieu of the
States, or if the tribe has implemented a tribe-wide air quality
implementation plan to which new permit applicants must comply, BOEM
would recognize this authority and grant the tribes the same authority
as a State to appeal BOEM's approval of plans for OCS development
activities. This authority would not be extended to all tribes,
however, since a tribe may elect not to establish any air quality
regulatory scheme. In the event that a tribe has not established its
own air quality regulatory mechanism, there is no reason that it should
have the same rights as a State under BOEM's regulations. Such a tribe
would, of course, retain all the rights of public comment on
rulemakings and to provide feedback to BOEM at public forums.
Although BOEM does not believe this proposed rule would cause any
substantial direct or adverse impact to any Indian tribe, in order to
inform such Indian tribe(s), DOI intends to initiate consultations with
potentially affected tribe(s) on a government-to-government basis
during the public comment period for this rule. BOEM will fully
consider all tribal views and concerns before issuing a final rule on
this topic.
7. Actions Concerning Regulations That Significantly Affect Energy
Supply, Distribution or Use (E.O. 13211) May 18, 2001
We have analyzed this proposed rule under E.O. 13211, ``Actions
Concerning Regulations That Significantly Affect Energy Supply,
Distribution, or Use'' and have determined this rule is not a
significant energy action under the definition in Executive Order
13211. The IRIA provides a general discussion of modeling, monitoring
and emission reduction compliance costs on potentially marginal GOM
development projects.
8. Enhancing Coordination of National Efforts in the Arctic (E.O.
13689) January 21, 2015
E.O. 13689 recognizes the Arctic has critical long-term strategic,
ecological, cultural, and economic value, and it is imperative we
continue to protect our national interests in the region, which
include: National defense; sovereign rights and responsibilities;
maritime safety; energy and economic benefits; environmental
stewardship; promotion of science and research; and preservation of the
rights, freedoms, and uses of the sea as reflected in international
law.
E.O. 13689 also recognizes it is vital that federal agencies work
together to enhance coordination on Arctic efforts. Pursuant to this
goal, the E.O. establishes an Arctic Executive Steering Committee
(Steering Committee), to provide ``guidance to executive departments
and agencies (agencies) and enhance coordination of federal Arctic
policies across agencies and offices, and, where applicable, with
State, local, and Alaska Native tribal governments and similar Alaska
Native organizations, academic and research institutions, and the
private and nonprofit sectors.'' DOI is a member of this Steering
Committee.
Consistent with DOI's long-standing commitment to coordinate with
other federal agencies on Artic matters, BOEM will work with the
Steering Committee and other relevant agencies, including the USEPA,
BSEE, FWS, NPS, BLM, and the Forest Service within the Department of
Agriculture.
The E.O. also recognizes ``it is in the best interest of the Nation
for the Federal Government to maximize transparency and promote
collaboration where possible with the State of Alaska, Alaska Native
tribal governments and similar Alaska Native organizations, and local,
private-sector, and nonprofit-sector stakeholders.'' BOEM intends to
take action consistent with this

[[Page 19796]]

objective in order to ensure the implementation of the underlying
goals.
9. Improving Regulation and Regulatory Review (E.O. 13563) January 18,
2011
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
regulations must be based on the best available science and the
rulemaking process must allow for public participation and an open
exchange of ideas. We have developed this rulemaking in a manner
consistent with these requirements.
Executive Order 13563 also calls for consideration regarding a
regulation's impact on employment. It states, ``Our regulatory system
must protect public health, welfare, safety, and our environment while
promoting economic growth, innovation, competitiveness, and job
creation.'' An analysis of employment impacts is a standalone analysis,
and these impacts are not included in the estimation of benefits and
costs.
BOEM does not expect the proposed rule's compliance cost will be
great enough to close operations or prevent new ones from starting.
However, employment reductions are possible in related activities if
operators chose to slow development due to the provisions of this
rulemaking. On the other hand, actions taken to comply with this
proposed rule also will create employment opportunities; for example,
consulting firms specializing in air quality analysis and modeling are
likely to experience increased employment demand. As more companies
need to model and maintain records of their emissions, new employment
opportunities in the broad field of air quality analysis will emerge.
While BOEM does not anticipate that companies will adopt an emission
reduction measure like post-combustion SCR, the companies that install
these mitigation technologies would benefit from increased demand for
their equipment.
The proposed rule is not expected to generate either large negative
or positive employment impacts. On balance, there will likely be
adjustments on both sides among companies directly and indirectly
affected by the regulation.
As stated in E.O. 12866, to the extent permitted by law, each
agency must, among other things: (1) Propose or adopt a regulation only
upon a reasoned determination its benefits justify its costs
(recognizing some benefits and costs are difficult to quantify); (2)
tailor its regulations to impose the least burden on society,
consistent with attaining regulatory objectives, taking into account,
among other things, and to the extent practicable, the costs of
cumulative regulations; (3) select, in choosing among alternative
regulatory approaches, those approaches that maximize net benefits
(including potential economic, environmental, public health and safety,
and other advantages; distributive benefits; and equity); (4) to the
extent feasible, specify performance objectives, rather than specifying
the behavior or manner of compliance that regulated entities must
adopt; and (5) identify and assess available alternatives to direct
regulation, including providing economic incentives to encourage the
desired behavior, such as user fees or marketable permits, or providing
information with which choices can be made by the public. BOEM has
evaluated these options and made the determination there is no
alternative that meets the need for this rulemaking and the proposed
rulemaking is the best alternative for addressing the important policy
objectives that BOEM is pursuing.
The proposed changes in this rulemaking would better ensure that
BOEM's air quality regulations conform to the requirements of OCSLA.
Unlike the current regulations, the proposed air quality requirements
would automatically be updated if the USEPA changed its standards as to
which pollutants are potentially harmful and at what levels of exposure
those pollutants cause harm. The proposed rule would replace various
provisions in the current regulations with more comprehensive and up-
to-date provisions based upon more recent science and technology. The
rule would better address DOI's mandate to evaluate the potential
impact of any OCS development with respect to the probable impacts to
most closely affected States.
10. Presidential Memorandum of June 1, 1998 on Regulation Clarity
E.O. 12866 (section 1(b)(2)), E.O. 12988 (section 3(b)(1)(B)), E.O.
13563 (section 1(a)), and the Presidential Memorandum of June 1, 1998,
require every agency write its rules in plain language. This means
that, wherever possible, each rule must: (a) Have a logical
organization; (b) use the active voice to address readers directly; (c)
use common, everyday words and clear language, rather than jargon; (d)
use short sections and sentences; and (e) maximize the use of lists and
tables.
If you feel we have not met these requirements, send your comments
to Peter.Meffert@boem.gov. To better help BOEM revise the proposed
rule, your comments should be as specific as possible. For example, you
should tell us the number of any section or paragraph that you think we
wrote unclearly, which section(s) or sentence(s) are too long, or the
section(s) where you believe lists or tables would be useful, etc.
Public Availability of Comments
We will post all comments, including names and addresses of
respondents, at www.regulations.gov. Before including your address,
phone number, email address, or other personal identifying information
in your comment, you should be aware we may make your entire comment--
including your personal identifying information--publicly available at
any time. While you can ask us in your comment to withhold your
personal identifying information from public view, we cannot guarantee
we will be able to do so.

List of Subjects in 30 CFR Part 550

Administrative practice and procedure, Air pollutant, Air
pollution, Air quality, Arctic, Attainment area, Continental shelf,
Compliance, Criteria pollutants, Development plan, Development and
production plan, Environmental assessments, Environmental impact
statements, Environmental protection, Exploration plan, Federal lands,
Federal Land Manger, Greenhouse gasses, Hazardous air pollutants,
Incorporation by reference, New source review, Non-attainment area, Oil
and gas exploration, Oil and gas development, Oil pollution, Oil
production, Outer Continental Shelf, Ozone, Penalties, Pipelines,
Precursor pollutants, Prevention of significant deterioration,
Reporting and recordkeeping requirements, Sulphur.

Dated: March 11, 2016.
Amanda C. Leiter,
Acting Assistant Secretary--Land and Minerals Management.

For the reasons stated in the preamble, the Bureau of Ocean Energy
Management, (BOEM) proposes to amend 30 CFR part 550 as follows:

[[Page 19797]]

PART 550--OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER
CONTINENTAL SHELF

0
1. The authority citation for 30 CFR part 550 is revised to read as
follows:

Authority: 30 U.S.C. 1751, 31 U.S.C. 9701, 43 U.S.C. 1334.

Subpart A--General

0
2. Revise the section heading for Sec. 550.101 to read as follows:

Sec. 550.101 Applicability.

0
3. Revise Sec. 550.102 to read as follows:

Sec. 550.102 What does this part do?

(a) 30 CFR part 550 contains the regulations of the BOEM Offshore
program that govern oil, gas and sulphur exploration, development and
production operations on the Outer Continental Shelf (OCS). These
regulations may require you, when conducting operations on the OCS, to
submit plans, requests, applications, and notices, and, upon request,
to submit supplemental information.
(b) The following table of general references shows where to look
for information about these processes.

Table to Sec. 550.102--Where To Find Information for Conducting
Operations
------------------------------------------------------------------------
For information about Refer to
------------------------------------------------------------------------
(1) Applications for permit to drill (APD) 30 CFR part 250, subpart D.
(2) Development and Production Plans (DPP) 30 CFR part 550, subpart B.
and Development Operations Coordination
Documents (DOCD).
(3) Downhole commingling.................. 30 CFR part 250, subpart K.
(4) Exploration Plans (EP)................ 30 CFR part 550, subpart B.
(5) Flaring............................... 30 CFR part 250, subpart K.
(6) Gas measurement....................... 30 CFR part 250, subpart L.
(7) Off-lease geological and geophysical 30 CFR part 551.
(G&G) Permits.
(8) Oil Spill Financial Responsibility 30 CFR part 553.
(OSFR) coverage.
(9) Oil and gas production safety systems. 30 CFR part 250, subpart H.
(10) Oil spill response plans............. 30 CFR part 254.
(11) Oil and gas well-completion 30 CFR part 250, subpart E.
operations.
(12) Oil and gas well-workover operations. 30 CFR part 250, subpart F.
(13) Platforms and structures............. 30 CFR part 250, subpart I.
(14) Rights-of-Use and Easement (RUE)..... 30 CFR part 550, subpart A.
(15) Pipelines and Pipeline Rights-of-Way 30 CFR part 250, subpart J
(ROW). and 30 CFR part 550,
subpart J.
(16) Sulphur operations................... 30 CFR part 250, subpart P.
(17) Training............................. 30 CFR part 250, subpart O.
(18) Unitization.......................... 30 CFR part 250, subpart M.
(19) Air Quality.......................... 30 CFR part 550, subpart C.
------------------------------------------------------------------------

0
4. Revise Sec. 550.105 as follows:
0
a. Revise the definition of ``Air pollutant'';
0
b. Delete the definitions of ``Attainment area'', ``Best available
control technology'', and ``Emission offsets'';
0
c. Add a definition for ``Emissions source'';
0
d. Delete the definitions of ``Existing facility'' and ``Facility'';
0
e. Add a definition for ``Federal Land Manager,''
0
f. Revise the definitions of ``Flaring'' and ``Minerals'';
0
g. Add a definition for ``Mobile support craft'';
0
h. Delete the definition of ``Nonattainment area'';
0
i. Add a definition for ``Offshore vehicle'';
0
j. Delete the definition of ``Projected emissions'';
0
k. Remove the definition for ``Right-of-use'' and add in its place a
definition for ``Right-of-use and easement (RUE)'';
0
l. Add a definition for ``State''; and
0
m. Revise the definition of ``Venting''.
The revisions and additions read as follows:

Sec. 550.105 Definitions.

* * * * *
Air pollutant means any of the following:
(1) Any criteria pollutant for which the U.S. Environmental
Protection Agency (USEPA) has established primary or secondary National
Ambient Air Quality Standards (NAAQS), in 40 CFR part 50, pursuant to
section 109 of the Clean Air Act (CAA);
(2) Any precursor air pollutant identified by the USEPA that
contributes to the formation of a criteria pollutant through a
photochemical or other reaction, including, but not limited to,
Volatile Organic Compounds (VOCs), ammonia (NH3), and those
criteria pollutants (CPs) that are also precursors for other CPs (such
as sulphur dioxide (SO2));
(3) any USEPA-defined Greenhouse Gas (GHG), as defined at 40 CFR
98.6, pursuant to section 111 of the CAA; and
(4) Any USEPA-defined Hazardous Air Pollutant, as defined at 40 CFR
63.2, pursuant to section 112 of the CAA.
* * * * *
Emissions source means a device or substance that emits air
pollutant(s) in connection with any authorized activity described in
your plan. Several emissions sources may exist on a single facility,
aircraft, vessel, or vehicle. Anything that: Produces or results in the
release of one or more air pollutant(s), including the flashing,
flaring or venting of natural gas, involves burning any oil or well
test fluids, or generates fugitive emissions, is an emissions source.
Examples include, but are not limited to: Boilers/heaters/burners,
diesel engines, drilling rigs, combustion flares, cold vents, glycol
dehydrators, natural gas engines, natural gas turbines, pneumatic
pumps, pressure/level controllers, amine units, tanks, dual fuel
turbines, sources involved in mud degassing, storage tanks, well
testing equipment, vessels (including support vessels, pipeline lay
barges, pipeline bury barges, derrick barges), and any other equipment
that could cause fugitive emissions, venting, losses from flashing, or
loading losses.
* * * * *
Federal Land Manager (FLM) means the Secretary of the Department
with authority over any federal Class I area or sensitive Class II area
(or the Secretary's designee).
Flaring means the burning of natural gas or other hydrocarbons and
the release of the associated emissions into the atmosphere. The term
``flaring'' is equivalent to combustion flaring (i.e., burning of the
gases), but is distinct from cold venting, which involves the discharge
of raw pollutants into the air without burning.
* * * * *
Minerals includes oil, gas, sulphur, geopressured-geothermal and
associated resources, and all other minerals that

[[Page 19798]]

are authorized by an Act of Congress to be produced from public lands.
* * * * *
Mobile support craft (MSC) means any offshore supply vessel (OSV)
as defined by the USCG in accordance with 46 U.S.C. 2101, and any ship,
tanker, tug or tow boat, pipeline barge, anchor handling vessel,
facility installation vessel, refueling or ice management vessel, oil-
spill response vessel, or any other offshore vessel, remotely operated
vehicle (ROV), or any offshore vehicle used by, or in the support of,
the offshore operations described in a plan. For the purpose of
evaluating air emissions, an MSC is considered a facility while
temporarily attached to the seabed or connected to another facility.
* * * * *
Offshore vehicle means a type of MSC that is capable of being
driven on ice and which provides support services or personnel to your
facility or facilities.
* * * * *
Right-of-use and easement (RUE) means seabed use authorization,
other than an OCS lease, that BOEM may grant at an OCS site pursuant to
Sec. Sec. 550.160 through 550.166 of this part.
* * * * *
State means any State of the United States (U.S.) extending to the
limit of the State seaward boundary (SSB), as defined in 43 U.S.C.
1301(b).
* * * * *
Venting means the release of gas into the atmosphere, including
though a stack without igniting it, whereby relief flows of natural gas
or other hydrocarbons are directed to an unignited flare or which are
otherwise discharged directly to the atmosphere. This includes gas that
is released underwater and bubbles to the atmosphere.
* * * * *
0
5. In Sec. 550.141, add paragraphs (d) and (e) and revise the title to
read as follows:

Sec. 550.141 May I use or be required to use alternate procedures or
equipment?

* * * * *
(d) In order to protect public health, you may be required or
allowed by the Regional Supervisor to temporarily suspend the use of
equipment that emits air pollutants, or to implement operational
control(s) on the use of such equipment, when an adjacent State or
locality declares an air quality episode or emergency, provided that
any such suspension or operational control(s) would not cause an
immediate threat to safety or the environment.
(e) With respect to published documents cited in these regulations,
including those incorporated by reference in Sec. 550.198, the
following provisions apply:
(1) In each instance, the applicable document is the one
specifically referred to, including any referenced supplement or
addendum, and not any other version, supplement or addendum, even if by
the same author, agency or publisher. You may comply with a later
edition of a specific document incorporated by reference, provided you
show that complying with the later edition provides a degree of
scientific or technical accuracy, environmental protection, or
performance equal to or better than would be achieved by compliance
with the listed edition; and you obtain the prior written approval for
alternative compliance from the authorized BOEM official.
(2) In the case of USEPA documents, you may always use the most
recent version approved by the USEPA.
0
6. In Sec. 550.160, redesignate current paragraphs (f), (g), (h) and
(i) as paragraphs (g), (h), (i) and (j) respectively, and add a new
paragraph (f) to read as follows:

Sec. 550.160 When will BOEM grant me a right-of-use and easement, and
what requirements must I meet?

* * * * *
(f) If you apply for a RUE with a facility as defined in Sec.
550.302 or you hold a RUE with such a facility, then you must submit
the information required by Sec. 550.205, except that the ten-year
periodic review requirement in Sec. 550.310(c) may be waived by the
Regional Supervisor. For the purposes of this section, any provisions
of those sections applicable to a lessee or operator should be read to
refer equally to any RUE applicant or any holder thereof. If the RUE is
approved or held as part of an existing or proposed plan, no additional
air quality requirements would apply to the plan.
* * * * *
0
7. Add Sec. 550.187 to subpart A to read as follows:

Sec. 550.187 What region-wide offshore air emissions data must I
provide?

(a) OCS emissions inventory. You, as a lessee, an operator, or a
holder of a RUE or pipeline ROW (whether or not that ROW includes an
accessory structure), must collect and maintain information regarding
all air pollutant emissions from all emissions sources associated with
your operations. You must retain this information for a period of no
less than 10 years. You must submit this information to the appropriate
regional office on an ongoing basis according to a schedule
corresponding to the schedule for the National Emissions Inventory as
established by the USEPA. If you have an emissions source that
generates facility emissions that have a potential to emit (PTE) such
that it would qualify as a Type A source according to USEPA's
regulations in table 1 of appendix A of subpart A (``Emission
Thresholds by Pollutant for Treatment as Point Source'') of 40 CFR
51.50, then, beginning in either 2017 or the next reporting period
after [EFFECTIVE DATE OF THE FINAL RULE], you must report this
information according to the timeframes specified in 40 CFR 51.30(b).
(b) The information provided must include the emissions of or the
activity data necessary to calculate the emissions of stationary
emissions sources, including all facilities, and all non-stationary
sources, including MSC(s) and any other non-stationary emissions
source(s) of air pollutants above the OCS or above State submerged
lands that operate in support of your facility or facilities, as
determined by the Regional Supervisor. You may request that the owner
of such non-stationary emissions source(s) provide the information to
BOEM or a BOEM-designated agent, but if the owner does not provide the
information, the lessee, operator, or RUE or pipeline ROW holder is
still responsible for submitting the required information.
(c) As part of the information required in this section, you must
submit, in a form and manner as specified by the Regional Supervisor:
(1) Your facility and equipment usage, including hours of operation
at each percent of capacity for each emissions source; and/or
(2) Your monthly and annual fuel consumption showing the quantity,
type, and sulphur content of fuel used for each emissions source that
generates air pollutants in connection with operations on the OCS.
(3) The information provided should be at a sufficient level of
detail so as to facilitate BOEM's compilation of a comprehensive OCS
emissions inventory of air pollutants.
(4) You must classify the emissions according to the appropriate
Source Classification Codes (SCCs) as defined by the USEPA in FIRE
Version 5.0: Source Classification Codes and Emission Factor Listing
for Criteria Air Pollutants, incorporated by reference in Sec.
550.198(b)(1)(iv).
(d) The Regional Director may waive or permit delay in compliance
with the

[[Page 19799]]

requirements of this section on a region-wide basis.
0
8. Add Sec. 550.198 to read as follows:

Sec. 550.198 Documents incorporated by reference.

(a) (1) Certain material is incorporated by reference into this
part with the approval of the Director of the Federal Register under 5
U.S.C. 552(a) and 1 CFR part 51. In each instance, the applicable
document is the one specifically referred to, including any referenced
supplement or addendum, and not any other version, supplement or
addendum, even if by the same author, agency or publisher. To enforce
any edition other than that specified in this section, BOEM will
publish a document in the Federal Register and the material will be
available to the public. All approved material is available for
inspection at the Bureau of Ocean Energy Management, Office of Policy,
Regulation and Analysis, 45600 Woodland Road, Sterling, Virginia 20166
or by phone at (703) 787-1610, and is available from the sources listed
below. It is also available for inspection at the National Archives and
Records Administration (NARA). For information on the availability of
this material at NARA, call 202-741-6030, or refer to: https://www.archives.gov/federal_register/code_of_federal_regulations/ibr_locations.html.
(2) The effect of incorporation by reference of a document into the
regulations in this part is that the incorporated document is a
regulatory requirement. When a section in this part incorporates all of
a document, you are responsible for complying with the provisions of
that entire document, except to the extent that the section which
incorporates the document by reference provides otherwise. When a
section in this part incorporates part of a document, you are
responsible for complying with that part of the document as provided in
that section. BOEM incorporated each document or specific portion by
reference in the sections noted. The entire document is incorporated by
reference, unless the text of the corresponding sections in this part
calls for compliance with specific portions of the listed documents. In
each instance, the applicable document is the specific edition or
specific edition and supplement or addendum cited in this section.
(b) Environmental Protection Agency, Office of Air and Radiation,
1200 Pennsylvania Ave. NW., MS6101A, Washington, DC 20460.
(1) AP 42, Fifth Edition, Compilation of Air Pollutant Emission
Factors, Volume 1: Stationary Point and Area Sources, January 1995,
incorporated by reference at Sec. 550.205(b.
(2) Motor Vehicle Emission Simulator (MOVES), User Guide,
Assessment and Standards Division, Office of Transportation and Air
Quality, EPA-420-B-14-055, July 2014, incorporated by reference at
Sec. 550.205(b).
(3) User's Guide for the Final NONROAD2005 Model, EPA420-R-05-013,
December 2005 incorporated by reference at Sec. 550.205(b).
(4) FIRE (Factor Information Retrieval System) Version 5.0: Source
Classification Codes and Emission Factor Listing for Criteria Air
Pollutants, EPA 454/R-95-012, August 1995, incorporated by reference at
Sec. 550.187(c).
(c) Federal Aviation Administration (FAA), Office of Environment
and Energy, (AEE-100), 800 Independence Avenue SW., Washington, DC
20591.
(1) Aviation Environmental Design Tool (AEDT) User's Guide, Version
2B, July 2015 (as amended) incorporated by reference at Sec.
550.205(b).
(2) Aviation Environmental Design Tool (AEDT), Version 2B, AEDT
Standard Input File (ASIF) Reference Guide, May 2015 (as amended)
incorporated by reference at Sec. 550.205(b).
(d) International Maritime Organization, 4 Albert Embankment,
London SE1 7SR, United Kingdom, or https://www.imo.org, or 44-(0)20-
7735-7611.
(1) Revised MARPOL (Marine Pollution) Annex VI, Regulations for the
Prevention of Air Pollution from Ships, and NOX Technical
Code [NTC] 2008, 2009 edition, incorporated by reference at Sec.
550.205(b).
(2) Revised MARPOL Annex VI, Regulations for the Prevention of
Pollution from Ships (``2008 Annex VI''), incorporated by reference at
Sec. 550.205(b.
(3) NOX Technical Code 2008, incorporated by reference
at Sec. 550.205(b).

Subpart B--Plans and Information

Sec. 550.200 [Amended]

0
9. Remove the definition of ``Offshore vehicle'' from Sec. 550.200:
0
10. Add Sec. 550.205 to read as follows:

Sec. 550.205 What air emissions information must be submitted with my
Plan (EPs, DPPs, DOCDs, or application for a RUE, pipeline ROW, or
lease term pipeline)?

All of the terms used in this section have the meaning described in
Sec. 550.302, unless defined in Sec. 550.105. Except if excluded from
the Air Quality Regulatory Program (AQRP) by paragraph (o) of this
section, the requirements in this section apply to all plans, RUE,
pipeline ROW, and lease term pipeline applications submitted in any
area of the OCS in which the Secretary of the Interior has authority to
regulate air quality on the OCS. Your plan must contain the following
criteria air pollutant and major precursor air pollutant emissions
information:
(a) Emissions sources. You must list and describe every emissions
source on or associated with any facility or facilities and MSC(s)
described in your plan. This includes each emissions source used during
the construction, installation (including well protection structure
installation), and operation of any exploration, testing, drilling
(including well test flaring), development, or production equipment or
facility or facilities (including every platform or manmade island
included in your plan). You must account for the air pollutant
emissions sources associated with all drilling operations, including
workovers and recompletions, sidetracking and from pipeline
construction. You must include emissions sources associated with your
use of oil or gas produced from your lease. The list of emissions
sources must cover the duration of the plan's proposed activities.
(1) For each emissions source, you must identify, to the extent
practicable:
(i) Equipment type and number, manufacturer, make and model,
location, purpose (i.e., the intended function of the equipment and how
it would be used in connection with the proposed activities covered by
the plan), and physical characteristics;
(ii) The type and sulphur content of fuel stored and/or used to
power the emissions source; and
(iii) The frequency and duration of the proposed use.
(2) For every engine on each facility, including non-road engines,
marine propulsion engines, or marine auxiliary engines, in addition to
the information specified under paragraph (a)(1) of this section, you
must identify and provide the engine manufacturer, engine type, and
engine identification, and the maximum rated capacity of the engine
(given in kilowatts (kW)), if available. If you have not yet determined
what specific engine will be available for you to use, you must provide
analogous information for an engine with the greatest maximum rated
capacity for the type of engine which you will use. If the engine has
any physical design or operational limitations and you choose to base
your emissions calculations on these limitations, then you must provide

[[Page 19800]]

documentation of these physical design or operational limitations.
(3) For engines on MSCs, including marine propulsion and marine
auxiliary engines, in addition to the information specified under
paragraph (a)(1) and (2) of this section, you must provide the engine
displacement and maximum speed in revolutions per minute (rpm). If the
specific rpm information is not available, indicate whether the rpm
would be less than 130 rpm, equal to or greater than 130 rpm but less
than 2,000 rpm, or equal to or greater than 2,000 rpm, based on best
available information. If the actual MSC engine types needed for
calculating emissions are unknown or cannot be verified, assume an MSC
possessing the maximum potential emissions for the type of MSC you
would typically use for your planned operations.
(4) For offshore vehicles, you must provide the information
specified under paragraph (a)(1) of this section. If the actual
offshore vehicle engine types needed for calculating emissions are
unknown or cannot be verified, assume an offshore vehicle possessing
the maximum emissions for the types of offshore vehicles you would
typically use for your planned operations.
(5) For any emissions source not described above, you must provide
all information needed to calculate and verify the associated
emissions, such as volumes vented, volumes flared, size of tank, and
number of components.
(b) Emissions factors. For each emissions source identified under
paragraph (a) of this section, you must identify the most appropriate
emissions factors used to calculate the emissions for every criteria
air pollutant and major precursor air pollutant emitted by that source.
(1) Emissions testing. You may use actual emissions amounts as
measured from emissions testing conducted on a specific emissions
source, in lieu of the standards or emissions factors for that source
which are described in paragraph (b)(2) of this section. However, if
none of the methods in paragraph (b)(2) of this section are applicable,
you must conduct stack testing on the emissions source to determine the
appropriate emissions factor. The data from stack testing may be used
only for the engine for which the stack testing was conducted. When
determining the emission factors through testing, you must consider:
(i) Test points and procedures. (A) In general, test points should
be devised based on actual operations as opposed to using the test
points and engine loads contained in one of the various marine duty
cycles. If, based on the unique circumstances of the proposed project,
this is impracticable, an alternative approach for defining test points
may be implemented with the approval of the Regional Supervisor. It
cannot be assumed that emissions per hour or emissions per kW hour or
horse-power hour from large main engines on drill ships and platforms
are highest during full load or near-full load operation. The emissions
factor and emission per hour or emissions per kW hour or horse-power
hour for the operation that is actually expected should be determined,
and the emissions under 90% load should be used only if emissions at
this load are the highest and thus conservative.
(B) Testing should be done consistent with the procedures outlined
in 40 CFR part 53 to the maximum extent practicable. Where the unique
circumstances or requirements of the proposed operations make such
procedures impracticable, alternative procedures may be implemented
with the approval of the Regional Supervisor. As appropriate, you must
use the General Provisions for Determining Standards of Performance for
New Stationary Sources, at 40 CFR 60.8.
(ii) Fuel. You must ensure that the fuel used in the testing to
generate the emission factors reflects the type of fuel that will be
used by the engine in actual operation and that the sulphur content of
the fuel is the same as that which will be used in the engine.
(2) In the event that you elect not to measure the actual emissions
for any given emissions source, select an emissions factor from one of
the following references (references are listed in priority order; you
may use a method only if all the methods identified above it are not
available):
(i) You may use the emissions factor(s) that are vendor-guaranteed
or provided by the manufacturer of the specific emissions source, if
available; where a manufacturer has not provided an emissions factor
for the emissions source you propose to use, you may use a
manufacturer's emissions factor for a similar source only if you can
demonstrate to the satisfaction of the Regional Supervisor that the
emissions generated by your emissions source are the same as or lower
than that for which a manufacturer's emissions factor is available. If
you elect to use vendor-guaranteed or manufacturer data, you must
demonstrate that:
(A) The fuel used by the manufacturer to generate the emission
factors reflects the type of fuel that will be used by the engine in
actual operation; and,
(B) The actual engine has not been modified outside the
configuration used to generate the emission factors; thus, the emission
factors used in the plan must represent the actual pattern of use for
that equipment in operations.
(ii) You may use emissions factors generated from source tests
required by the USEPA OCS permits as BOEM emission estimates for a
specific rig. If emissions factors were not generated through testing
for a particular engine, emissions factors generated from a recent and
similar permit engine may be used. Data from a rig from the same
manufacturer, having an engine of the same model and year is generally
allowed, unless the Regional Supervisor has a reason to believe that
such data may not be accurate or reliable.
(iii) You may use a model or table, as appropriate, developed by
the USEPA or FAA, if available and appropriate to the emissions source,
and you may use the emissions factors from that model or table.
(A) For commercial marine engines operating aboard MSC, excluding
vehicles and aircraft, apply emission factors based on the
classification of the engine (i.e., category 1, category 2, and
category 3), the year the engine was manufactured, and the maximum
engine power expressed in kW. Some category 3 engine emission factors
are based on rpm rather than maximum engine power. Engine category,
year, model, and emission factors, by kW power rating, are given in 40
CFR 1042.101 for category 1 and category 2 commercial engines and
consider the useful life provisions of each engine category. Engine
category, year, model, and emission factors, by rpm rating, are given
in 40 CFR 1042.104 for category 3 commercial marine engines, and also
consider the useful life provisions for each engine category.
(B) For non-road equipment used on the drill ships or platforms,
non-road emission factors, rather than marine engine emission factors
may be used. The primary source for these emission factors is the
NONROAD portion of the Motor Vehicle Emission Simulator (MOVES) model
(https://www.epa.gov/otaq/models/moves/index.htm), as incorporated by
reference at Sec. 550.198. Depending on the type of engine, the
NONROAD2008A Model may also be used, as incorporated by reference at
Sec. 550.198. That model is available at https://www.epa.gov/otaq/nonrdmdl.htm.
(C) For storage tanks, use the USEPA's TANKS model, or the most
recent USEPA-recommended update or replacement, to generate emission
factors, such as the AP 42 Compilation of Emissions Factors, Chapter
VII, incorporated by reference at Sec. 550.198.

[[Page 19801]]

(D) In the event that you are required to report emissions data
from aircraft, use emissions factors generated by the AEDT,
incorporated by reference at Sec. 550.198, or from another appropriate
model, or set of models, approved by the FAA, in the event that the
AEDT does not contain emissions factors for the relevant aircraft
proposed in your plan. AEDT emissions factors are available at: https://www.faa.gov/about/office_org/headquarters_offices/apl/research/models/aedt/.
(iv) You may use an emission factor from a published study
conducted by a reputable source, such as the California Air Resources
Board, a university, or research agency, if such source yields reliable
emission factors or formula(s) to calculate emissions factors for
certain types of engines and equipment other than for the large main
engines on drilling ships and drill platforms and for locomotive-sized
engines powering cranes. If an emission study is used, the study must
cover representative engines, fuels, and duty cycles.
(v) For non-U.S. flagged vessels having non-USEPA-certified,
MARPOL-certified marine engines, you may use the MARPOL Annex VI
standards, available from the International Maritime Organization,
incorporated by reference at Sec. 550.198, or the Revised MARPOL Annex
VI, Regulations for the Prevention of Pollution from Ships,
incorporated by reference at Sec. 550.198, as appropriate taking
vessel flag as well as engine size into account when determining the
emission factor that should apply to an engine. With respect to
calculations specifically for NOX emissions or emissions
factors, any reporting must comply with the NOX Technical
Code [NTC] 2008 incorporated by reference at Sec. 550.198. If this
method is used, the plan must account for any differences in the
sulphur limits of the fuel being used and the sulphur limit of the fuel
used for emission testing. All fuel used by the subject drilling ships
and offshore platforms must either be purchased in the U.S. or comply
with applicable CAA fuel emissions requirements, unless the lessee or
operator can demonstrate that it has properly accounted for any
differences in emissions that may result from the use of non-U.S. fuel.
(vi) For a natural gas-powered engine of any rated capacity, or for
a non-road diesel-powered engine with a maximum rated capacity less
than 900 kW, or for a non-engine emissions source, you may use the
appropriate emissions factor from the Compilation of Air Pollutant
Emission Factors, Volume 1: Stationary Point and Area Emissions
Sources, or any update thereto, incorporated by reference at Sec.
550.198; or,
(vii) If you elect to use the methods described in paragraph
(b)(2)(v) or (vi) of this section, you must take appropriate account of
the deterioration in the performance of the equipment based on its age
and the potential variation of the actual emissions from the standard
to account for the maximum potential emissions that the emissions
source may emit. Given that equipment tends to operate less efficiently
over time, you should make an appropriate upward adjustment in the
emissions estimates for older equipment. At any time you revise your
plan, including resubmissions every ten years, you must consider the
age of the equipment, adjust for any change in operating efficiency,
and provide the associated emissions factors in your revised or
resubmitted plan, as applicable.
(3) If the Regional Supervisor has reason to believe that any air
emissions factor used in your plan is inappropriate, or new or updated
information on emissions factors becomes available, the Regional
Supervisor may require you to use a different emissions factor for any
emissions source for any air pollutant. The Regional Supervisor may
require you to perform stack testing, in accordance with paragraph
(b)(1) of this section, or some other form of validation to verify the
accuracy of an emissions factor.
(4) If you propose to utilize an engine or equipment that is not
certified by the USEPA for use in the U.S., you may not use a USEPA
emissions factor intended to apply to a certified engine or equipment.
If you propose to utilize an engine or equipment that is USEPA-
certified, then you must submit documentation of its certification.
(5) If your projected emissions include emissions for a U.S.
flagged vessel, you must submit documentation of the USEPA-issued
Certificate of Conformity for each engine on the vessel.
(6) If you propose to use any non-U.S. engine or equipment on a
non-U.S. flag vessel that is not MARPOL-compliant, you may not use an
emissions factor intended to apply to a MARPOL-compliant engine or
equipment.
(c) Facility emissions. For each criteria and major precursor air
pollutant, calculate the projected annual emissions for each of your
facilities, the maximum 12 month rolling sum of facility emissions and
the maximum projected peak hourly emissions using the following
procedures:
(1) Calculate total emissions generated annually by each emissions
source on or physically connected to each of the facilities described
in your plan that would result from the construction, installation,
operation, or decommissioning of the facility. Such calculations should
be done for each year that the plan states that the operator proposes
to engage in operating activities, up to ten years. This calculation
should be based on the maximum rated capacity of each emissions source
associated with the facility, or the capacity that generates the
highest rate of emissions, and the facility's maximum potential
projected annual emissions, using the methods and procedures specified
under paragraphs (a) and (b) of this section.
(2) Calculate the maximum 12-month rolling sum of emissions from
each emissions source on or physically connected to each facility and
the maximum 12-month rolling sum of emissions from each facility that
would result from the construction, installation, operation, or
decommissioning of the facility. Identify the 12-month period used for
this calculation. This should be the 12-month period during which your
facility generates the highest amount emissions over the life of your
plan.
(3) Calculate the maximum projected peak hourly emissions from each
emissions source on or physically connected to each facility and the
maximum projected peak hourly emissions from each facility that would
result from the construction, installation, operation, or
decommissioning of the facility.
(d) Attributed emissions. For each criteria and major precursor air
pollutant, calculate the attributed projected annual emissions for each
of your MSCs, the maximum 12-month rolling sum of each MSC's emissions,
and the maximum projected peak hourly emissions for each MSC, using the
following procedure:
(1) For each facility described in your plan, identify the MSCs
that will be used to support that facility. To the extent practicable,
identify the other facilities that each MSC will support.
(2) For each MSC referred to in paragraph (d)(1) of this section:
(i) An MSC that is intended to remain at sea continuously (i.e., a
vessel that does not typically return to port on a regular basis)
should be assumed to operate on a 24-hour basis for any day the MSC
operates in the waters overlying the OCS or State submerged lands.
(ii) For all other MSCs, calculate the emissions per trip,
irrespective of what

[[Page 19802]]

other facilities the MSC may also service on each trip. These emissions
include all the emissions generated between the time that the MSC
leaves its port or home base until it returns (i.e., support emissions
per trip). All calculations must be based on the maximum rated capacity
or the capacity that generates the highest rate of emissions, if
greater, for each emissions source on the MSC.
(3) Multiply the emissions per trip from paragraph (d)(2) of this
section by the number of trips the MSC will make during the 12 month
period described in paragraph (c)(2) of this section to get the total
support emissions for that MSC. If the MSC will remain at sea
continuously, multiply the emissions it will generate per day by the
number of days that it will operate in support of your facility during
the 12 month period described in paragraph (c)(2) of this section.
(4) If the MSC provides support only to your facility, then you
must attribute the MSC's total support emissions to that facility.
(5) For each MSC described in paragraph (d)(1) of this section that
supports multiple facilities, you may attribute the total support
emissions for that MSC to your facility or you may attribute a portion
of its total support emissions to your facility (i.e., calculate the
attributed emissions for that MSC) using the following procedure:
(i) Subtract the emissions you can document that should be
reasonably allocated to other facilities from the total support
emissions calculated under paragraph (d)(3) of this section for that
MSC; or
(ii) If it is not practicable to use the method in paragraph
(d)(5)(i) of this section, divide the total support emissions
calculated under paragraph (d)(3) of this section by the lowest number
of facilities that the MSC will service on a typical trip; or
(iii) Where it is not practicable to use either paragraph (d)(5)(i)
or (ii) of this section, calculate the greater of:
(A) The emissions that would be generated by the MSC traveling
round-trip between the port or home base and the facility; or
(B) The emissions generated by the MSC for the entire time it will
operate within 25 statute miles of the facility.
(6) Calculate the sum of the emissions estimates that result from
the calculation in paragraph (d)(4) or (5) of this section for every
MSC identified in paragraph (d)(1) of this section. That sum represents
the attributed emissions for your facility.
(7) All calculations must be based on the maximum rated capacity or
the capacity that generates the highest rate of emissions for each of
the relevant sources on every MSC.
(8) If BOEM questions your determination of the attributed
emissions, the Regional Supervisor may require additional documentation
to support your findings and may direct you to make changes, as
appropriate.
(e) Projected emissions. For every facility described in your plan,
you must identify the maximum projected emissions for each criteria and
major precursor air pollutant by calculating the annual rate (for each
calendar year), the maximum 12-month rolling sum, and the maximum peak
hourly rate for your facility emissions under paragraph (c)(2) of this
section and your attributed emissions under paragraph (d)(6) of this
section.
(1) If any of your proposed facilities would be located in such a
manner as to potentially constitute proximate activities with a pre-
existing facility or a facility that was previously approved but not
yet constructed, you must identify any such facility in your plan.
(2) If you are required to consolidate air emissions from multiple
facilities, in accordance with the provisions of Sec. 550.303(d), you
must provide the projected emissions information for each facility and
provide the complex total emissions for all of the consolidated
activities.
(f) Emission reduction measure(s) (ERM). You must provide a
description of all proposed ERM, including: the affected emissions
source(s); the proposed emissions reduction control technologies,
procedures and/or operational limits; the emission control
efficiencies; the projected quantity of reductions to be achieved; and
any monitoring or monitoring system you propose to use to measure or
evaluate the associated emissions. You must be able to demonstrate that
all ERM meet the requirements of Sec. 550.309.
(g) Modeling information. If you are required to conduct any air
quality modeling in support of your plan, then you must provide:
(1) Table(s) of the appropriate and relevant maximum projected air
pollutant concentrations over any area(s) of any State(s), including
the most affected attainment area(s) and the most affected non-
attainment area(s);
(2) Table(s) of the appropriate and relevant maximum projected air
pollutant concentrations over any Class I area(s), if relevant;
(3) The maximum projected concentrations resulting from the
projected emissions for each of your facilities, for each criteria air
pollutant and major precursor air pollutant, for the corresponding
averaging time(s) (e.g., 1-hour, 3-hour, 8-hour, 24-hour, annual, etc.)
specified in the tables in 40 CFR 51.165(b)(2), 40 CFR 52.21(c), and 40
CFR part 50;
(4) A list of all inputs, assumptions, and default values used for
modeling and justification for each, including the source and
justification for the proposed meteorological information;
(5) The name and version of the model(s), and whether the model is
listed on the USEPA preferred list of models in 40 CFR part 51 appendix
W; and
(6) A modeling report, including the modeling results. If you have
previously provided such a report and/or results of the analysis
relevant to paragraphs (e) and (g) of this section to the Regional
Supervisor, and the projected emissions are the same as or lower than
in the previously submitted report(s) or results, you may instead
provide a reference to such report and/or results.
(7) For each MSC, provide the distance from each facility described
in your plan to the closest relevant home port (for MSCs other than
offshore vehicles) or home base (for offshore vehicles), consistent
with the maps and information you provide under Sec. 550.224(e) or
550.256(b).
(h) Requirements applicable to specific air pollutants--(1)
Nitrogen and Sulphur Oxides (NOX and SOX).
Various documents cross-referenced by these regulations, refer to
NOX and NO2 (nitrogen dioxide) or
SOXand SO2 (sulphur dioxide). Whenever possible,
you must utilize data or reasonable estimates for NOX and
SOX. At a minimum, your projected emissions of
NOX must include emissions of nitrogen oxide and
NO2, and your projected emissions of SOX must
include emissions of SO2. In the event that data on
NOX or SOX emissions are not available, you must
instead utilize data on nitrogen oxide plus NO2 as a
substitute for NOx, and SO2 emissions as a substitute
SOX.
(2) Particulate Matter (PM10 and PM2.5). For
each emissions source, you must provide data and information on both
PM10 (PM that is 10 micrometers or less in diameter) and
PM2.5 (PM that is 2.5 micrometers or less in diameter)
whenever such information is available and evaluate each type of
particulate matter (PM) separately under every applicable standard. All
reporting of PM2.5 must include the sum of filterable and
condensable PM. In the event that data for PM is not separately
available for both PM10 and PM2.5 for any given
source, you must utilize the PM10 data for the
PM10 analysis and the same data for the PM2.5
analysis. A plan that does not contain separate emission

[[Page 19803]]

exemption threshold and modeling analysis for each type of PM will not
be considered complete.
(3) Hydrogen Sulfide (H2S). All emissions of
SOX that result from the flaring of hydrogen sulfide must be
included in the projected emissions of SOX reported and
analyzed as part of your plan, in accordance with the USEPA's Oil and
Natural Gas Sector New Source Performance Standards and National
Emission Standards for Hazardous Air Pollutants Reviews. If your
projected emissions of H2S will potentially exceed the
USEPA's Significant Emission Rate for H2S, as defined in 40
CFR 51.166(b)(23)(i), you must report the nature and extent of these
emissions and their likely impact as part of your plan.
(4) Methane (CH4). Unless specifically directed to the
contrary by another regulatory provision, the analysis or reporting of
CH4 emissions is not required.
(5) Ozone (O3). Generally reporting is not required other than in
accordance with the provisions of Sec. 550.304(b), unless another
regulatory provision specifically addresses O3.
(6) Lead (Pb) or Ammonia (NH3). Reporting of emissions for these
pollutants, for any given source, is required: if there are published
manufacturer specifications of emissions factors for these pollutants;
or if such information is available from the USEPA or could be obtained
or derived from another recognized source, such as utilizing a mass
balance approach. If you intend to use a source known to emit a
potentially significant amount of Pb or NH3, then you must
obtain a reasonable estimate of the associated Pb or NH3
emissions. Zero emissions for these pollutants should be assumed in the
situation where relevant data are not available and neither you nor
BOEM have a reason to anticipate that the emissions could be
potentially significant.
(i) Distance calculations--(1) Distance from shore. For each
facility described in your plan, you must calculate and provide the
distance in statute miles, as measured in a straight line from the site
of the facility to the closer of:
(i) The nearest mean high water mark of a State, or, on the Pacific
coast, the nearest mean higher high water mark; or
(ii) The nearest Class I area of any State.
(2) Distance from SSB. For each facility described in your plan,
you must calculate and provide the distance in statute miles, as
measured in a straight line from the site of the facility to the
closest point at which the OCS borders any State, at the SSB.
(j) Documentation. You must collect, create, and maintain records
or any data or information establishing, substantiating, and verifying
the basis for all information, data, and resources used to calculate
your projected emissions under this section. The emissions factors you
propose to use must be documented, and any relevant certifications,
citations, methods, and procedures used to obtain or develop emissions
factors must be retained. You must collect and maintain all
documentation pertaining to the modeling analysis under Sec.
550.205(g), if applicable, including all references and copies of any
referenced materials, as well as any data or information related to any
ERM that you propose or implement. You must provide this information,
unless the Regional Supervisor waives this requirement for good cause.
(k) Compliance. You must provide a description of how you will
comply with Sec. 550.303 when the emissions generated by your proposed
plan activities exceed the respective emission exemption thresholds
(EETs), calculated using the formulas in Sec. 550.303(c). If you are
subject to the requirement to monitor and report your actual emissions
in accordance with Sec. 550.311, then the description you provide must
describe how you propose to monitor your emissions.
(l) Reporting. You must submit data and information in a format,
and using the forms, as specified by BOEM. You must submit information
in an electronically-readable format, unless otherwise directed by the
Regional Supervisor. If you transmit the information to BOEM
electronically, you must use a delivery medium or transmission method
authorized by BOEM.
(m) Additional information. (1) If you are required to conduct
modeling, and if, under Sec. 550.305 your projected emissions would
cause an increase in the concentration of any pollutant that is within
95% of any Significant Impact Level (SIL), then you must: Report the
amount of emissions from aircraft or onshore support facilities as
attributed emissions; and combine the impacts of aircraft and onshore
support facilities emissions with the impacts of your projected
emissions for the purposes of this section and for your analysis under
subpart C of this part. The aircraft and support facilities for which
you are required to report emissions are those described in Sec. Sec.
550.224, 550.225, 550.257, and 550.258. If required to report your
aircraft or onshore support facilities and those aircraft or onshore
support facilities support multiple OCS facilities then you must
allocate their emissions in an appropriate manner similar to that
described for MSCs in Sec. 550.205(d).
(2) The Regional Supervisor may require such additional data or
information related to these sources as is necessary to demonstrate
your plan's compliance with subpart C of this part, and/or applicable
federal laws related to the protection of air quality within BOEM
jurisdiction.
(n) Requirements for plans to be deemed submitted. Your plan will
not be deemed submitted in accordance with the requirements of Sec.
550.231 or Sec. 550.266 until:
(1) All of the requirements of this section have been completed;
(2) You have completed the Ambient Air Increment (AAI) analysis,
including the required BOEM forms, the modeling protocol, and the
modeling results, as specified in Sec. 550.307(b) if required; and
(3) You have completed any other analysis required by subpart C of
this part.
(o) Plans exempt from review under the AQRP. If you can demonstrate
that your facility will not generate projected emissions of any
criteria or precursor air pollutant in an amount greater than the
corresponding significant emissions rate limit described in the
``Pollutant and Emissions Rate'' table defined in 40 CFR
52.21((b)(23)(i), your plan is exempt from the AQRP requirements of
this section and subpart C of this part.
0
11. Revise Sec. 550.211(c) to read as follows:

Sec. 550.211 What must the EP include?

* * * * *
(c) Drilling unit. (1) A description of the drilling unit and
associated equipment you will use to conduct your proposed exploration
activities, including a brief description of its important safety and
pollution prevention features, and a table indicating the type and the
estimated maximum quantity of fuels, oil, and lubricants that will be
stored on the facility.
(2) For purposes of this section, the term ``facility'' means any
installation, structure, vessel, vehicle, equipment or device that is
temporarily or permanently attached to the seabed of the OCS, including
an artificial island used for drilling, well completion, well-workover,
or other operations.
* * * * *
0
12. Revise Sec. 550.212(f) to read as follows:

Sec. 550.212 What information must accompany the EP?

* * * * *

[[Page 19804]]

(f) Air emissions information required by Sec. 550.205;
* * * * *
0
13. Amend Sec. 550.215 by revising paragraph (d)(2) and adding
paragraph (e) to read as follows:

Sec. 550.215 What hydrogen sulfide (H2S) information must
accompany the EP?

* * * * *
(d) * * *
(2) If any H2S emissions are projected to affect any
location within a State in a concentration greater than 10 parts per
million, the modeling analysis must be consistent with the USEPA risk
management plan methodologies outlined in 40 CFR part 68.
(e) Hydrogen sulfide. If you propose to flare any gasses containing
a potentially significant amount of H2S, you must separately
identify this activity in your plan and separately identify the
resulting emissions of sulphur oxides (SOX) as part of your
projected emissions under Sec. 550.205(e).

Sec. 550.218 [Removed and reserved]

0
14. Remove and reserve Sec. 550.218.
0
15. Revise Sec. 550.224(a) and (b) to read as follows:

Sec. 550.224 What information on support vessels, offshore vehicles,
and aircraft you will use must accompany the EP?

* * * * *
(a) General. A description of the MSCs and aircraft you will use to
support your exploration activities. The description of MSCs must
estimate the storage capacity of their fuel tanks and the frequency of
their visits to your facility or facilities.
(b) Air emissions. See Sec. 550.205.
* * * * *
0
16. Revise Sec. 550.225(b) to read as follows:

Sec. 550.225 What information on the onshore support facilities you
will use must accompany the EP?

* * * * *
(b) Air emissions. A description of the emissions source, the
frequency and duration of its operation, and the types of air
pollutants likely to be emitted by the onshore support facilities you
will use. Except as required under Sec. 550.205(m), the amount of air
pollutants emitted need not be reported. You do not need to report this
information for any onshore support facility if the facility is
permitted under the CAA or if you can identify another agency to which
this emissions information from the facility was submitted.
* * * * *
0
17. Revise paragraphs Sec. 550.241(c) and (d) to read as follows:

Sec. 550.241 What must the DPP or DOCD include?

* * * * *
(c) Drilling unit. A description of the drilling unit and
associated equipment you will use to conduct your proposed development
drilling activities. Include a brief description of its important
safety and pollution prevention features, and a table indicating the
type and the estimated maximum quantity of fuels and oil that will be
stored on the facility. For the purpose of this section, the term
facility means any installation, structure, vessel, vehicle, equipment
or device that is temporarily or permanently attached to the seabed of
the OCS, including an artificial island used for drilling, well
completion, well-workover, or other operations.
(d) Production facilities. A description of the production
platforms, satellite structures, subsea wellheads and manifolds, lease
term pipelines (see definition at Sec. 550.105), production
facilities, umbilicals, and other facilities you will use to conduct
your proposed development and production activities. Include a brief
description of their important safety and pollution prevention
features, and a table indicating the type and the estimated maximum
quantity of fuels and oil that will be stored on the facility. For the
purpose of this section, the term facility means a vessel, a structure,
or an artificial island used for drilling, well completion, well-
workover, or other operations or used to support production facilities.
* * * * *
0
18. Revise Sec. 550.242(g) to read as follows:

Sec. 550.242 What information must accompany the DPP or DOCD?

* * * * *
(g) Air emissions information required by Sec. 550.205;
* * * * *
0
19. Amend Sec. 550.245 by revising paragraph (d)(3) and adding
paragraph (e) to read as follows:

Sec. 550.245 What hydrogen sulfide (H2S) information must
accompany the DPP or DOCD?

* * * * *
(d) * * *
(3) If any H2S emissions are projected to affect any
location within a State in a concentration greater than 10 parts per
million, the modeling analysis must be consistent with the USEPA risk
management plan methodologies outlined in 40 CFR part 68.
(e) Hydrogen sulfide. If you propose to flare any gasses containing
a potentially significant amount of hydrogen sulfide, you must
separately identify this activity in your plan and separately identify
the resulting emissions of SOX, including reporting the
sulphur emissions under Sec. 550.205(e).

Sec. 550.249 [Removed and reserved]

0
20. Remove and reserve Sec. 550.249.
0
21. Revise paragraphs Sec. 550.257(a) and (b) to read as follows:

Sec. 550.257 What information on the support vessels, offshore
vehicles, and aircraft you will use must accompany the DPP or DOCD?

* * * * *
(a) General. A description of the MSCs and aircraft you will use to
support your activities. The description of MSCs must estimate the
storage capacity of their fuel tanks and the frequency of their visits
to the facilities you will use to conduct your proposed development and
production activities.
(b) Air emissions. See Sec. 550.205.
* * * * *
0
22. In Sec. 550.258, revise paragraph (b) to read as follows:

Sec. 550.258 What information on the onshore support facilities you
will use must accompany the DPP or DOCD?

* * * * *
(b) Air emissions. A description of the source, the frequency and
duration of its operation, and the types of air pollutants likely to be
emitted by the onshore support facilities you will use. Except as
required under Sec. 550.205(m), the amount of emissions of air
pollutants need not be reported. You do not need to report this
information for any onshore support facility if the facility is
permitted under the CAA or if you can identify another agency to which
emissions from the facility was submitted.
* * * * *

Post-Approval Requirements for an EP, DPP, DOCD, RUE, Pipeline ROW or
Lease Term Pipeline Application

0
23. Revise the undesignated center heading that occurs before Sec.
550.280 to read as set out above.
0
24. In Sec. 550.280, revise the section heading and the introductory
text of paragraph (a) to read as follows:

Sec. 550.280 How must I conduct activities under the approved EP,
DPP, DOCD, RUE, pipeline ROW, or lease term pipeline application?

(a) Compliance. You must conduct all of your lease and unit
activities according to your approved EP, DPP, DOCD, or RUE, pipeline
ROW, or lease term pipeline application, and any approval conditions.
You may not install or use any facility, equipment,

[[Page 19805]]

vessel, vehicle, or other emissions source not described in your EP,
DPP, DOCD, or RUE, pipeline ROW or lease term pipeline application, and
you may not install or use a substitute for any emissions source
described in your EP, DPP, DOCD, or RUE, pipeline ROW, lease term
pipeline application, without BOEM prior approval. If you fail to
comply with your approved EP, DPP, DOCD, or RUE, pipeline ROW, or lease
term pipeline application:
* * * * *
0
25. In Sec. 550.284, revise the section heading, paragraph (a)
introductory text, and (a)(1) to read as follows:

Sec. 550.284 How will BOEM require revisions to the approved EP, DPP,
DOCD or application for a RUE?

(a) Periodic review. The Regional Supervisor will periodically
review the activities you conduct under your approved EP, DPP, DOCD, or
RUE application and may require you to submit updated information on
your activities. The frequency and extent of this review will be based
on the significance of any changes in available information, applicable
law or regulation, or onshore or offshore conditions affecting, or
affected by, the activities in your approved EP, DPP, DOCD, or RUE
application. After 2020, any EP, DPP, DOCD or RUE application that was
approved more than ten years prior must be resubmitted for air quality
review in accordance with the requirements of Sec. 550.310.
* * * * *
0
26. Revise subpart C to read as follows:

Subpart C--Air Quality Analysis, Control, and Compliance

Sec.
550.300 [Reserved]
550.301 Under what circumstances does this subpart apply to
operations in my plan?
550.302 Acronyms and definitions concerning air quality.
550.303 What analysis of my projected emissions is required under
this subpart?
550.304 What must I do if my projected emissions exceed an emission
exemption threshold?
550.305 How do I determine whether my projected emissions of
criteria air pollutants require ERM?
550.306 What ERM are required for a short-term facility?
550.307 What ERM are required for a long-term facility?
550.308 Under what circumstances will BOEM require additional ERM on
my proposed facility or facilities?
550.309 What requirements apply to my ERM?
550.310 How will revisions to the ambient air quality standards and
benchmarks (AAQSB) affect my plan?
550.311 Under what circumstances will I be required to measure and
report my actual emissions?
550.312 What post-approval recordkeeping and reporting is required?
550.313 Under what circumstances will BOEM impose additional
requirements on facilities operating under already approved plans?
550.314 Under what circumstances will the Regional Supervisor review
the projected emissions from my existing facility or facilities?

Sec. 550.300 [Reserved]

Sec. 550.301 Under what circumstances does this subpart apply to
operations in my plan?

The provisions of this subpart apply to any existing facility or
proposed plan involving a facility or facilities operating on, or
proposed to operate on, any area of the OCS where the Secretary of the
Interior has authority to regulate air emissions pursuant to section
5(a)(8) of the Outer Continental Shelf Lands Act (OCSLA), 43 U.S.C.
1334(a)(8), as amended, and jurisdiction pursuant to section 328(b) of
the CAA, 42 U.S.C. 7627(b), as amended, including OCS operations
conducted pursuant to any plan approved under this part.

Sec. 550.302 Acronyms and definitions concerning air quality.

(a) Acronyms and terms used in this subpart, and in Sec. 550.205,
have the following meanings:

AAI means ambient air increment(s).
AAQSB means ambient air quality standards and benchmarks.
AEDT means aviation environmental design tool.
APD means application for a permit to drill.
AQCR means air quality control region.
BACT means best available control technology.
BLM means the Bureau of Land Management.
Btu IT means British Thermal Unit International Tables.
CAA means the Clean Air Act.
CEO means Chief Environmental Officer (BOEM)
CH4 means methane.
CO means carbon monoxide.
CP means criteria pollutant.
CSU means column-stabilized-units.
DOCD means development operations coordination document.
DOI means the U.S. Department of the Interior.
DPP means development and production plan.
ECE means emission control efficiency.
EET means emission exemption threshold(s).
EIS means environmental impact statement.
EP means exploration plan.
ERM means emission reductions measure(s).
FAA means Federal Aviation Administration.
FLM means Federal Land Manager, which includes the heads of the U.S.
Bureau of Land Management (BLM), Fish and Wildlife Service (FWS),
National Park Service (NPS), Bureau of Land Management (BLM) in DOI
and U.S. Forest Service in the Department of Agriculture.
FPS means floating production systems.
FPSO means floating production storage and offloading vessel.
G&G means geological and geophysical.
GHG means greenhouse gas.
hp means horsepower.
hpm means mechanical horsepower.
HPU means hydraulic power unit.
H2S means hydrogen sulfide.
kW means kilowatt.
MARPOL means Marine Pollution Convention.
MODU means mobile offshore drilling unit.
MOVES means motor vehicle emission simulator.
MSC means mobile support craft.
NAAQS means the primary or secondary national ambient air quality
standards.
NARA means National Archives and Records Administration.
NH3 means ammonia.
NO2 means nitrogen dioxide.
NOX means nitrogen oxides.
O3 means ozone.
OCS means Outer Continental Shelf.
OCSLA means Outer Continental Shelf Lands Act.
ONRR means the Office of Natural Resources Revenue
OSFR means oil spill financial responsibility.
OSV means offshore supply vessel.
Pb means lead.
PM means particulate matter.
PM2.5 means fine particulate matter equal to or less than
2.5 micrometers in diameter.
PM10 means particulate matter equal to or less than 10
micrometers in diameter.
PTE means potential to emit.
ROW means rights-of-way.
Rpm means revolutions per minute.
RUE means right-of-use and easement.
SILs means significant impact levels.
SO2 means sulphur dioxide.
SOX means sulphur oxides.
SSB means State seaward boundary
TAS means treatment as State.
TIP means tribal implementation plan.
TLP means tension-leg platforms.
VOC means volatile organic compound.
U.S. means the United States.
USEPA means the United States Environmental Protection Agency.
[mu]g/m\3\ means micrograms per cubic meter.

(b) Terms used in this subpart have the following meanings:
Air quality control region (AQCR) means an interstate area or major
intrastate area, which the USEPA deems appropriate for assessing the
regional attainment and maintenance of the primary or secondary
national ambient air quality standards described in 42 U.S.C. 7409, as
provided under 40 CFR part 81, subpart B, Designation of Air Quality
Control Regions.
Ambient Air Increments (AAIs) means the national benchmarks for
Ambient Air Increments set out in the table in 40 CFR 52.21(c), as
amended, or in 42 U.S.C. 7473 et seq., as amended.

[[Page 19806]]

Ambient air quality standards and benchmarks (AAQSB) means any or
all of the national ambient air quality standards and benchmarks
referenced in this subpart, including the primary and secondary NAAQS
defined in 40 CFR part 50; the SILs, in 40 CFR 51.165(b)(2); the AAIs,
as set out in the table in 40 CFR 52.21(c).
Attainment area means, for any given criteria air pollutant, a
geographic area, which is not designated by the USEPA as being a
designated non-attainment area, as codified at 40 CFR part 81 subpart C
(40 CFR 81.300 through 81.356). This includes areas that are referred
to as attainment, maintenance, unclassifiable, or unclassifiable/
attainment in that subpart, as well as areas that have not yet been
designated because the two-year period to complete such designations
after revision of a NAAQS has not yet passed.
Attributed emissions means, for any given criteria or precursor air
pollutant, the emissions from MSC and, if appropriate, aircraft,
operating above the OCS or State submerged lands, that are attributed
to a facility pursuant to the methodology set forth in Sec. 550.205(d)
for the period over which the corresponding facility emissions are
measured.
Background concentration means the ambient air concentration of any
given criteria air pollutant that arises both from local natural
processes and from the transport into the airshed of natural or
anthropogenic pollutants originating locally or from another location,
either as measured from an USEPA-approved air monitoring system or as
determined on some other appropriate scientifically justified basis
approved by BOEM.
Baseline concentration means the ambient background concentration
of any given air pollutant that exists or existed at the time of the
first application for a USEPA Prevention of Significant Deterioration
(PSD) permit in an area subject to section 169 of the CAA, based on air
quality data available to the USEPA or a State air pollution control
agency and on the monitoring data provided in the permit application
and as defined in 40 CFR 51.166(b)(13). The baseline concentration is
distinguished from the background concentration in that the background
concentration changes continually over time to reflect the current
ambient air concentration for any given air pollutant, whereas the
baseline concentration remains fixed until such time as a new AAI is
established for an attainment area.
Best Available Control Technology (BACT) means a physical or
mechanical system or device that reduces emissions of air pollutants
subject to regulation to the maximum extent practicable, taking into
account: The amount of emissions reductions necessary to meet specific
regulatory provisions; energy, environmental, and economic impacts; and
costs.
Class I area means an area designated by the USEPA, a State, or a
Federally-recognized Indian tribe, where visibility and air emissions
are protected by a FLM to pursuant to 42 U.S.C. 7472(a) or 7474, as
amended; Class I areas include certain national parks, wilderness
areas, national monuments, and areas of special national or regional
natural, recreational, scenic, or historic value.
Class II area means an area designated by the USEPA, a State, or a
Federally-recognized Indian tribe, that is protected pursuant to 42
U.S.C. 7472(a) or 7474, as amended, to limits less stringent than those
for Class I areas. Sensitive Class II areas represent a sub-
classification of Class II areas that are defined by Federal Land
Management Agencies as federal lands where the protection of air
resources has been prioritized, as specified in acts, regulations,
planning documents, or by policy.
Complex total emissions means the sum of the facility emissions
that would result from all of the facilities that have been aggregated
for the purposes of evaluating their potential consolidated impact on
air quality, pursuant to the methodology set forth in Sec. 550.303(d),
and the sum of all corresponding attributed emissions for those
facilities.
Criteria air pollutant or criteria pollutant means any one of the
principal pollutants for which the USEPA has established and maintains
a NAAQS under 40 CFR part 50 in accordance with 42 U.S.C. 7409, as
amended, for the protection of public health and welfare, and the
environment. The USEPA has established primary standards for the
protection of sensitive populations of children and the elderly and
secondary standards for the protection of crops, vegetation, buildings,
visibility, and prevention of harm to animals. Criteria air pollutants
do not include Volatile Organic Compounds (VOCs) or any other precursor
air pollutant not already regulated under the NAAQS.
Design concentration means the pollutant concentration at a given
location projected, through computer-simulated air dispersion or
photochemical modeling, as described under 40 CFR part 51, appendix W,
section 7.2.1.1 to result from your projected emissions, combined with
the background concentration for the same pollutant, averaging time,
and statistical form at the most appropriate receptor location. The
appropriate background concentration is measured from the nearest point
at which there is data from an USEPA-approved air monitoring system, or
as determined on some other appropriate scientifically justified basis
approved by BOEM.
Dispersion modeling means the mathematical computer simulation of
air emissions being transported from a source through the atmosphere
under given meteorological conditions. Emissions from sources,
expressed as the rate of air pollutants emitted over time (i.e., pounds
per hour), are translated through computer modeling into pollutant
concentrations, expressed in units of micrograms of pollutants per
cubic meter of ambient air ([micro]g/m3), or in parts per million or
billion, depending on the circumstances. When a file containing
meteorological and emissions data are input into the computer model,
the model will project the concentrations of the pollutants at a
receptor location.
Emission control efficiency (ECE) means the effectiveness of an ERM
for any given emissions source and air pollutant. The greater the
emission control efficiency, the greater the effectiveness of the
underlying controls (i.e., measured as a percentage reduction in the
underlying emissions of any given pollutant). ECE varies from 100%,
representing a control that completely eliminates emissions, to zero,
representing a control that has no effect on such emissions.
Emissions credits mean emissions reductions from an emissions
source(s) not associated with the plan that are intended to compensate
for the excessive emissions of criteria or precursor air pollutants,
regardless of whether these emissions credits are acquired from an
emissions source(s) located either offshore or onshore, including:
Emissions offsets generated by the lessee or operator itself; or
emissions offsets acquired from a third party; or trading allowances or
other alternative emission reduction method(s) or system(s) associated
with a market-based trading mechanism; examples include mitigation
banks or other competitive markets where these assets are exchanged.
Emission exemption threshold(s) (EET) means the maximum allowable
rate of projected emissions, calculated for each air pollutant,
expressed as short tons per year (tpy), above which facilities would be
subject to the requirement to perform modeling.
Emissions factor(s) means a value that relates the quantity of a
specific pollutant released into the atmosphere with the operation of a
particular

[[Page 19807]]

emissions source. Emissions factors are usually expressed as the mass
of pollutant generated from each unit (e.g., mass, volume, distance,
work, or duration) of activity by the emissions source emitting the
pollutant.
Emission reduction measure(s) (ERM) means any operational
control(s), equipment replacement(s), BACT, or emissions credit(s),
applied on either a temporary or permanent basis, to reduce the amount
of emissions of criteria or precursor air pollutants that would occur
in the absence of such measures.
Existing facility means an operational OCS facility described in an
approved plan.
Facility means, any installation, structure, vessel, vehicle,
equipment, or device that is temporarily or permanently attached to the
seabed of the OCS, including but not limited to a dynamically
positioned ship, gravity-based structure, manmade island, or bottom-
sitting structure, whether used for the exploration, development,
production or transportation of oil, gas, or sulphur. All
installations, structures, vessels, vehicles, equipment, or devices
directly associated with the construction, installation, and
implementation of a facility are part of a facility while located at
the same site, attached, or interconnected by one or more bridges or
walkways, or while dependent on, or affecting the processes of, the
facility, including any ROV attached to the facility. One facility may
include multiple drill rigs, drilling units, vessels, platforms,
installations, devices, and pieces of equipment. Facilities include
Mobile Offshore Drilling Unit(s) (MODU), even while operating in the
``tender assist'' mode (i.e., with skid-off drilling units), or any
other vessel engaged in drilling or downhole operations, including
well-stimulation vessels. Facilities also include all Floating
Production Systems (FPSs), including Column-Stabilized-Units (CSUs),
Floating Production, Storage and Offloading facilities (FPSOs),
Tension-Leg Platforms (TLPs), and spars. Any vessel used to transfer
production from an offshore facility is part of the facility while
physically attached to it. Facilities also include all DOI-regulated
pipelines and any installation, structure, vessel, equipment, or device
connected to such a pipeline, whether temporarily or permanently, while
so connected.
Facility emissions means, for any given criteria or precursor air
pollutant, the annual, the maximum 12-month rolling sum, and the peak
hourly emissions from all emissions sources on or connected to a
facility.
Federally-recognized Indian tribe refers to a Federally-recognized
Indian tribe that has either a Treatment as State (TAS) status
recognized by the USEPA or an approved TIP.
Fugitive emissions means the emissions of an air pollutant from an
emissions source that do not pass through a stack, chimney, vent, or
other functionally-equivalent opening.
Fully reduce(d) means to decrease emissions of VOCs to a rate that
will not exceed the emission exemption threshold calculated under Sec.
550.302, or to decrease emissions of criteria air pollutants to a rate
that will not exceed the Significant Impact Levels set out in the table
in 40 CFR 51.165(b)(2).
Long-term facility means a facility that has remained or is
intended to remain in the same lease block or within one nautical mile
of its original location for three years or longer; this three year
period is measured from the time the facility is first attached to the
seafloor, or another facility, and continues to run until the
facility's planned operations cease, regardless of the length of time
the facility remains attached to the seafloor in any given year.
Major precursor pollutant means any precursor pollutant for which
the States are required to report actual emissions to the USEPA, as
defined in 40 CFR 51.15(a).
MARPOL-certified engine means either:
(1) An engine with a power output of more than 5,000 kW and a per
cylinder displacement at or above 90 liters installed on a ship
constructed on or after January 1, 1990 but prior to January 1, 2000
that is subject to regulation 13.7 of MARPOL Annex VI; or
(2) An engine with a power output of more than 130 kW built on or
after January 1, 2000 that is subject to regulations 13.1 through 13.6
of MARPOL Annex VI.
Maximum rated capacity means the maximum power an engine is capable
of generating over time, expressed in kW, and if necessary, as
converted from hpm (where 1 hpm of power equals 745.699872 Watts or
0.745699872 kW) or from the International Table values of British
thermal units (BtuIT, where 1 BtuIT/hour of power equals 0.29307107
Watts or 0.00029307107 kW).
National ambient air quality standards (NAAQS) means the ambient
air standards established by the USEPA, as mandated by the CAA (42
U.S.C. 7409), set out in in 40 CFR part 50, for the common criteria air
pollutants considered harmful to public health or welfare. There are
two categories of the NAAQS: Primary standards that set limits to
protect public health, including the health of ``sensitive''
populations such as asthmatics, children, and the elderly; and
secondary standards that set limits to protect public welfare when
concentrations are elevated over time, including protection against
visibility impairment; prevention of harm to animals, including marine
mammals, fish and other wildlife; and avoidance of damage to crops,
vegetation, and buildings. This term includes both categories.
Non-attainment area means, for any given criteria air pollutant, a
geographic area, which the Administrator of the USEPA has designated as
non-attainment for a NAAQS, as codified at 40 CFR part 81 subpart C.
For the purposes of these regulations, all other areas will be
considered Attainment areas.
Operational control means a process, method or technique, other
than a physical or mechanical control, or equipment replacement that
reduces the emissions of criteria or precursor air pollutants (e.g.,
limitation on period of operation, load balancing, and/or use of less-
polluting fuels).
Particulate matter (PM) means an airborne contaminant of
particulate matter that is regulated as a criteria air pollutant under
the ambient air standards. PM10 refers to airborne
contaminants of particulates less than or equal to 10 micrometers.
PM2.5, or fine PM, is an airborne contaminant composed of
particulates less than or equal to a diameter of 2.5 micrometers.
Plan means any initial, revised, modified, resubmitted, or
supplemental Exploration Plan (EP), Development and Production Plan
(DPP), Development Operations Coordination Document (DOCD), or
application for a Right-of-Use and Easement (RUE), a Pipeline ROW, or a
lease term pipeline application.
Potential to emit (PTE) means the maximum capacity of a source to
emit a pollutant under its physical and operational design. Any
physical or operational limitation on the capacity of the source to
emit a pollutant, including air pollution control equipment and
restrictions on hours of operation or on the type or amount of material
combusted, stored, or processed, will be treated as part of its design
if the limitation or the effect it would have on emissions is federally
enforceable. Attributed emissions are not counted in determining a
facility's PTE.
Precursor air pollutant or precursor pollutant means a compound
that chemically reacts with other atmospheric gases to form a criteria
air pollutant. Some precursor air pollutants

[[Page 19808]]

are also defined as criteria air pollutants. Precursor air pollutants
include VOCs, NOX, SOX, and NH3.
Projected emissions means, for any given criteria or precursor air
pollutant, the sum of facility's (or facilities') emissions and the
corresponding attributed emissions over the specified time period, with
the controlled or uncontrolled nature of the pollutants specified by
the context.
Proximate activities means activities that involve or affect any of
the following: The same well(s); a common oil, gas, or sulphur
reservoir; the same or adjacent lease block(s); or, facilities located
within one nautical mile of one another. Where a well is drilled from
one facility, but production from that well will ultimately take place
through a different facility, the drilling and production activities
constitute proximate activities if they occur within the same twelve
months.
Sensitive Class II area means a Class II area defined by an FLM
agency as being federal land where protection of air resources has been
prioritized, as specified in acts, regulations, planning documents, or
policy.
Short-term facility means any facility that is not a long-term
facility or connected to a long-term facility.
Significance level or Significant impact level (SIL) means an
ambient air benchmark or limit that applies to the ambient air impact
of the emissions of a criteria air pollutant, as set out in the table
in 40 CFR 51.165(b)(2).
Technically feasible means a technology or methodology that: Has
been demonstrated to operate successfully on the same type of emissions
source as the one under review; or is available and applicable to the
type of emissions source under review.
Total support emissions means, for any criteria or precursor air
pollutant, the total emissions generated by an MSC that operates in
support of your and any other facilities, for the 12-month period over
which the corresponding facility emissions are measured. For example,
for any given MSC, the total support emissions would equal the number
of service trips (i.e., from the port to the supported facilities) made
during the relevant 12-month period multiplied by the average number of
hours per service trip multiplied by the emissions per hour for all
emissions source(s) on that MSC (derived from the emissions factor
calculation).

Sec. 550.303 What analysis of my projected emissions is required
under this subpart?

(a) Establishing emission exemption thresholds. BOEM establishes
the rate of projected emissions, calculated for each air pollutant,
above which facilities would be subject to the requirement to perform
modeling. These EETs establish those rates of emissions below which
BOEM has determined emissions would not significantly affect the air
quality of any State. If your projected emissions or complex total
emissions are exempt, then you will not be required to perform air
quality modeling in accordance with the requirements of Sec. 550.304
and to apply any controls, as described in Sec. Sec. 550.305 through
550.307.
(b) Calculating projected emissions. You must compare your
projected emissions, or your complex total emissions if you are
required to consolidate multiple facilities under paragraph (d) of this
section, with the EETs, pursuant to the following methodology:
(1) Projected emissions. You must calculate and report the
projected emissions for each facility as set forth in Sec. 550.205(e).
(2) Attributed emissions. You must calculate and report all
attributed emissions for each facility as set forth in Sec.
550.205(d).
(c) Exempt emissions thresholds. BOEM will establish EETs under
this paragraph. These will determine whether your projected emissions
or complex total emissions have the potential to significantly affect
the air quality of any State.
(1) BOEM will establish new EETs based on the factors listed in
this paragraph and publish them in the Federal Register. BOEM may
establish different EETs that apply to different areas of the OCS or
that apply to different kinds of emissions sources. BOEM may establish
different EETs that apply to different areas of the OCS or that apply
to different kinds of emissions sources. If your projected emissions
for any criteria air pollutant or precursor air pollutant exceeds an
EET, then you will be required to perform air quality modeling in
accordance with the requirements of Sec. 550.304 and you may be
required to apply controls, as described in Sec. Sec. 550.305 through
550.307, unless scientific evidence and the application of the factors
set in paragraph (c)(2) of this section demonstrates otherwise.
(i) The first time that BOEM establishes a new set of EETs, BOEM
will publish a notice in the Federal Register describing the proposed
EETs and will specify the length of a corresponding comment period. At
the conclusion of the comment period, BOEM will review and evaluate the
comments and make a determination as to the final EETs. BOEM will
publish a subsequent notice in the Federal Register listing the new
EETs, along with a corresponding effective date for the new EETs.
(ii) Any time that BOEM determines that a revised EET should be
established, BOEM will publish a notice in the Federal Register
describing the proposed revised EET and will specify the length of a
corresponding comment period. At the conclusion of the comment period,
BOEM will review and evaluate the comments and make a determination as
to the final EET. BOEM will publish a subsequent notice in the Federal
Register listing revised EET, along with a corresponding effective date
for the revised EET.
(iii) Until the date of the notice described in paragraph
(c)(1)(ii) of this section, a facility will not be exempt under this
section if its projected emissions of any pollutant exceed EETs as
calculated using the following formulas:

(A) EET = 3400 x D^2/3 for emissions of carbon monoxide (CO);
and
(B) EET = 33.3 x D for emissions of each of the following: Nitrogen
oxides
(NOX); SOX; volatile organic compounds (VOCs);
and PM10.

Where D is the distance of the facility from the shoreline, as
identified in Sec. 550.205(i)(1).
(C) For Pb, the EET value is the level defined in 40 CFR
52.21(b)(23)(i).
(iv) Subsequent to the date of the notice, a facility will not be
exempt under this section if its projected emission of any pollutant
exceeds an EET published in the notice.
(v) Because the USEPA's AAQSB are subject to change as scientific
knowledge improves and because modeling and evaluation techniques may
improve over time, BOEM will revise EETs on an ongoing basis. Thus, as
the USEPA revises the NAAQS, or any applicable SIL or AAI, BOEM, at its
discretion, will periodically revise its EET formula(s) or its
amount(s) for the corresponding air pollutant(s), as appropriate.
(2) BOEM will determine new EET formulas taking into account the
following factors:
(i) The absolute level of projected emissions;
(ii) The distance of the proposed facility or facilities from any
State or from areas critical to natural resources, animals, and
habitats;
(iii) The existing ambient air pollution in potentially affected
States, trend in the ambient air pollution in those States, the
associated attainment status of such areas, and the associated effects
to public health and welfare;

[[Page 19809]]

(iv) Any USEPA AAQSB applied in this part;
(v) The types, frequency, and duration of any air pollutant
emissions and their formation and/or dispersion characteristics;
(vi) The characteristics of the facility or facilities and MSCs,
including the type and nature of the emissions sources, and the height
of the associated points or stacks;
(vii) Prevailing meteorological characteristics in any given area,
including air stability, relevant wind speeds and directions;
(viii) The amount of emissions from existing facilities and vessels
in the vicinity of the proposed facility; and
(ix) Other necessary and appropriate considerations.
(3) BOEM will set the EET formulas within the following ranges:
(i) The minimum values in this range are determined by the formulas
in table 1 to Sec. 550.303.

Table 1 to Sec. 550.303
------------------------------------------------------------------------
Pollutant * and averaging
Minimum value equation period
------------------------------------------------------------------------
Emin = 0.677(d \1.2693\).................. Annual NOX, SOX, and PM10.
Emin = 0.2031(d \1.2693\)................. Annual PM2.5.
Emin = 3.3851(d \1.2693\)................. 24-hr SO2 and PM10.
Emin = 0.8124(d \1.2693\)................. 24-hr PM2.5.
Emin = 1354(d \1.2693\)................... 1-hr CO.
Emin = 338.51(d \1.2693\)................. 8-hr CO.
Emin = 16.926(d \1.2693\)................. 3-hr SO2.
Where d is the distance in statute miles from the State seaward
boundary, as reported in your plan under Sec. 550.205(i)(2) and Emin
equals tons per year.
------------------------------------------------------------------------
* For Pb, the minimum value amount is the level defined in 40 CFR
52.21(b)(23)(i).

(ii) The maximum values of this range are set by the following
formulas:

(A) If d <= 3, then Emax = 7072 for CO; and Emax = 100 for
NOX, SOX, VOCs, and PM10.
(B) If d > 3, then Emax = 3400 x d^2/3 for CO; and Emax =
33.3 x d for NOX, SOX, VOCs, and PM10.

Where d will be the distance of the facility from the SSB as
identified in Sec. 550.205(i)(2).
(4) If your projected emissions for any criteria air pollutant or
precursor air pollutant exceeds the EETs as determined pursuant to
Sec. 550.303, then you will be required to perform air quality
modeling in accordance with the requirements of Sec. 550.304 and you
may be required to apply controls, as described in Sec. Sec. 550.305
through 550.307.
(d) Consolidation of air pollutant emissions from multiple
facilities. (1) You must report the projected emissions from multiple
facilities which may have been or are described in multiple plans, as
the complex total emissions for your plan, if:
(i) The air pollutant emissions are generated by proximate
activities (i.e., the same well(s); a common oil, gas, or sulphur
reservoir; the same or adjacent lease block(s); or, by facilities
located within one nautical mile of one another); and
(ii) You wholly or partially own, control or operate those
facilities; in the event of a dispute as to what constitutes common
ownership, control or operations, BOEM will make a determination by
reference to the ONRR criteria defined in 30 CFR 1206.101 and 1206.151;
and
(iii) The construction, installation, drilling, operation, or
decommissioning of any of your facilities occurs within a
contemporaneous 12-month period as the construction, installation,
drilling operation, or decommissioning of any other facility; and
(iv) Such a consolidation of emissions from multiple facilities
would generate emissions sufficient to exceed an applicable emission
exemption threshold (based on the exemption review described in
paragraphs (e) or (f) of this section).
(2) If any two or more facilities meet all of the conditions
specified in (d)(1)(i) through (iii) of this section, you must
calculate the sum of the projected emissions from those facilities
(including their respective attributed emissions) as the complex total
emissions for your plan.
(3) BOEM will make a determination that you have appropriately
considered the relevant data in your analysis of the complex total
emissions.
(4) If you are required to consolidate projected emissions data
from multiple facilities, then anywhere a requirement applies to
projected emissions you must instead use complex total emissions,
except with respect to the process by which projected emissions are
determined for any given facility (as specified in Sec. 550.205(d)).
(e) Emissions do not exceed any threshold. If none of your
projected emissions or complex total emissions of any precursor or
criteria air pollutant exceeds the applicable emission exemption
threshold, then your projected emissions are de minimis, and no further
analysis is required under this subpart.
(f) Emissions exceed a threshold. If your projected emissions or
complex total emissions of the precursor or criteria air pollutant
exceed the applicable emission exemption threshold, then further review
and/or controls are required, in accordance with the provisions below:
(1) If the exceedance is for VOCs, you must control your emissions
of VOCs in accordance with Sec. 550.306, for a short-term facility, or
Sec. 550.307, for a long-term facility.
(2) If the exceedance is for any criteria air pollutant, then you
must conduct modeling in accordance with Sec. 550.304.
(3) If the exceedance is for NOX, VOCs, or CO, and if
the conditions specified in Sec. 550.304(b) have been met, you are
required to conduct photochemical modeling for O3.
(4) If the exceedance is for NOX, VOCs,
PM2.5, or SOX, and if the conditions specified in
Sec. 550.304(b) have been met, you are required to conduct
photochemical modeling for PM2.5.
(g) Changes to previously approved plans. (1) If you change your
plan implementation, such that your projected emissions, or your
complex total emissions, will occur in years other than those that were
previously approved, you must submit a revised plan, and that revised
plan must be approved before you implement the proposed changes.
(2) If at any time you anticipate an increase in the maximum air
pollutant emissions from a previously approved plan, you must submit a
revised plan, pursuant to 30 CFR 550.283(a)(4).
(3) If you propose to make a change to your operations on your
existing facility or facilities, but not to the equipment used in such
operations, and your approved projected annual emissions in any given
year are higher than those previously approved for the particular year,
but lower than the maximum air pollutant emissions for any year, you do
not need to submit a revised plan--as long as the operations would
occur in the same year as described in the previous plan.
(4) If you propose to make a change to the equipment on your
existing facility or facilities in a year or years where your plan
already anticipated operations, and your proposed change would result
in an increase in air pollutant emissions from that equipment for any
air pollutant, you must submit a revised plan.
(5) If your plan was approved for a short-term facility that
becomes a long-term facility, then you must submit a revised plan for
review and approval by BOEM.
(h) Federal land manager. If BOEM believes that your proposed
activities may affect a Class I or a Sensitive Class II area of a
State:
(1) BOEM may consult with one or more relevant FLMs to determine
what

[[Page 19810]]

effects could result from your proposed activities.
(2) BOEM will consider the views of the FLMs in determining whether
your plan complies with the provisions of this subpart. Based on this
consultation, BOEM may require additional information and analysis,
either prior to or as a condition of approving your plan.
(3) If the FLM does not raise any concerns regarding your plan in a
timely manner, BOEM will assume that the FLM has no objections to the
proposed plan.

Sec. 550.304 What must I do if my projected emissions exceed an
emission exemption threshold?

If your projected emissions or your complex total emissions exceed
the limits defined in Sec. 550.303(c) for any criteria or precursor
pollutant, you must conduct modeling of that pollutant, and any other
pollutant for which that pollutant is a precursor, to project the
impacts of those emissions.
(a) Dispersion models. (1) You must use one or more of the
following air dispersion models:
(i) A model approved by the USEPA, as described in appendix A to
appendix W of 40 CFR part 51 (Summaries of Preferred Air Quality
Models); or
(ii) A model included in the Federal Land Managers' Air Quality
Related Values Workgroup Guidance; or
(iii) Another model approved by the BOEM Chief Environmental
Officer (CEO).
(iv) The BOEM CEO may disapprove the use of a USEPA-approved or
FLM-approved air quality model, if the CEO determines that such model
would not be appropriate in the OCS context.
(2) You must follow the modeling procedures recommended in 40 CFR
part 51 appendix W, to the extent possible. You must provide BOEM with
a copy of your dispersion modeling protocol and the associated data and
assumptions used to do your analysis before you conduct modeling.
(b) Photochemical models. Photochemical modeling is required only
if:
(1) Your projected emissions (or your complex total emissions where
applicable) for the relevant precursor air pollutants exceed an
applicable EET;
(2) An appropriate photochemical air quality model is available
that:
(i) Meets the USEPA's requirements of section 3.2 of appendix W to
40 CFR;
(ii) Complies with the Federal Land Managers' Air Quality Related
Values Workgroup Guidance; or
(iii) Is another model approved by the BOEM CEO;
(3) BOEM has determined that adequate relevant information on
background concentrations is available for the relevant location(s) in
a potentially affected State(s).
(4) Upon request, you must provide BOEM with a copy of your
photochemical modeling protocol and the associated data and assumptions
used to do your photochemical analysis before you conduct modeling.
(c) Projected emissions. Base your modeling on the maximum
projected emissions, as reported under Sec. 550.205(e), or on the
complex total emissions, where applicable;
(d) Meteorology. Apply the best available and most recent
meteorological dataset, either as directed in 40 CFR part 51 appendix
W, or by using an alternate dataset approved by the Regional
Supervisor.
(e) Estimates of ambient air concentrations. For each criteria air
pollutant resulting from your projected emissions (or complex total
emissions where applicable), estimate the peak incremental
concentrations projected in any attainment area(s) and, separately, in
any non-attainment area(s), in any State (over State submerged lands or
onshore), both on an annual basis and for the other averaging times
specified in the appropriate USEPA regulations at 40 CFR part 50 and
the tables at 40 CFR 51.165(b)(2) and 40 CFR 52.21(c).
(1) To the extent practicable, your estimate of the incremental
ambient air concentrations of any criteria air pollutant must consider
not only the dispersion of each criteria air pollutant itself, but also
the formation of any criteria air pollutant that may result from the
dispersion or presence of any relevant precursor air pollutant(s).
Specifically:
(i) Any analysis of PM2.5 must include NOX,
SOX, VOCs, and NH3
(ii) Any analysis of O3 must include NOX,
VOCs, and CO.
(2) BOEM may provide information though a Notice to Lessees to
assist lessees and operators in evaluating existing ambient air
concentrations, or changes in such concentrations over time if it
determines that there is an effective means of estimating ambient air
quality.
(i) In the event that BOEM has established appropriate background
concentration data, or baseline concentration data, for any given
pollutant, at any given location and point in time, you must use the
data provided by BOEM.
(ii) In the event that BOEM has not established appropriate
background concentration data for any given pollutant, for any given
location, and point in time, you should use the relevant data from the
USEPA for the closest appropriate location, as specified by the
Regional Supervisor.
(f) Attributed emissions. Conduct modeling of attributed emissions
from those locations where the emissions are expected to occur (i.e.,
utilizing a line, area, volume, or pseudo point source model).
(g) Documentation and reporting. Create a modeling report
documenting all emissions sources, inputs, parameters, assumptions,
procedures, methods, and results, including input and output files, and
data upon which your analysis under this subpart is based, and provide
BOEM with this report, copies of all data and access to any programs
used in your modeling.

Sec. 550.305 How do I determine whether my projected emissions of
criteria air pollutants require ERM?

(a) For all criteria air pollutants other than PM2.5 and
O3, compare the results of the modeling described in Sec.
550.304 with the SILs set out in the table at 40 CFR 51.165(b)(2). If
the modeling results exceed a SIL for any criteria air pollutant for
any averaging time, you are required to apply ERM to sources to reduce
emissions only for the CPs that exceed a SIL, as specified in Sec.
550.306 for a short-term facility, or as specified in Sec. 550.307 for
a long-term facility.
(b) For PM2.5, you must add the results of your
dispersion modeling of direct PM2.5 emissions conducted
under Sec. 550.304(a) to the results of your photochemical modeling,
if required under Sec. 550.304(b), before you compare the results with
the PM2.5 SILs set out in the table at 40 CFR 51.165(b)(2).
If this sum exceeds a SIL for PM2.5 for any averaging time,
you are required to apply ERM for a short-term facility as specified in
Sec. 550.306, or as specified in Sec. 550.307, for a long-term
facility.
(c) For O3, you must add the results of your
photochemical modeling, if required under Sec. 550.304(b), to the
existing background concentrations, as described under Sec. 550.302,
and determine if the sum exceeds the NAAQS for O3 for any
averaging time. If so, for a short-term facility, you must apply ERM as
specified in Sec. 550.306, or as specified in Sec. 550.307 for a
long-term facility.

Sec. 550.306 What ERM are required for a short-term facility?

(a) If any short-term facility requires ERM under Sec. 550.303(f)
for VOCs or Sec. 550.305 for a CP, then you are required to conduct an
ERM analysis to determine potential control options and their likely
cost effectiveness. In

[[Page 19811]]

conducting your ERM analysis, you must:
(1) Identify all available control technologies relevant to the
emissions of the pollutant(s) for which ERM is required;
(2) Determine which of these options are technically feasible for
your plan; a demonstration of technical infeasibility must be clearly
documented and must show, based on physical, chemical or engineering
principles, that technical difficulties would preclude the successful
use of the applicable emission control technology or methodology.
(3) Rank the technically feasible control technologies by their
emission control efficiencies (ECE) and determine their likely
reduction of criteria air pollutant emissions (i.e., absolute
effectiveness), in tpy of emissions avoided;
(4) Evaluate the most effective ERM and document the results of
your analysis; and
(5) Select reasonable operational controls or replacement(s) of
equipment that are technically and economically feasible and that are
designed to limit your facility's projected emissions to the greatest
practicable extent, taking into consideration the effectiveness and the
cost of implementation, for each option considered. You must
demonstrate that you have chosen the most effective technically and
economically feasible operational controls or replacement(s) of
equipment for every pollutant requiring such controls that can be
implemented cost effectively. As an alternative, you may propose an
equivalent reduction through the use of emissions credits.
(6) If you can demonstrate to the satisfaction of the Regional
Supervisor that no technically feasible operational controls or
equipment replacement(s) can be implemented cost effectively, then;
(i) For any given pollutant, if your emissions would affect only
attainment areas, no ERM will be required with respect to that
pollutant beyond that which was proposed in your plan.
(ii) If your emissions affect any non-attainment area for a
specific pollutant, the Regional Supervisor may require the
implementation of other ERM for that pollutant in lieu of operational
controls or equipment replacement(s) as a condition of approving your
plan. For any proposed BACT, you must provide a description of the
associated energy, environmental, and economic impacts, and other
costs.
(b) Unless you demonstrate to the satisfaction of the Regional
Supervisor that no technically feasible control technology can be
implemented cost effectively, your plan must include:
(1) An evaluation of the ERM you select, quantifying and verifying
the emission reduction measure(s) and associated cost(s);
(2) A description of how your selected operational controls or
replacement(s) of equipment meet the criteria in Sec. 550.309 for
emission reduction measures; and a calculation of your revised
projected emissions (or complex total emissions, where applicable),
taking into account your selected operational controls or
replacement(s) of equipment.
(c) Upon making a commitment to apply the appropriate operational
controls or replacement(s) of equipment or other ERM in lieu of
operational controls or replacement(s) of equipment, BOEM may approve
your plan, provided all other applicable requirements have been met.
(d) In the event that BOEM obtains information or data that would
indicate that your projected emissions may cause the NAAQS to be
exceeded, the Regional Supervisor may require you to provide additional
data, analysis, or modeling to demonstrate compliance with the NAAQS or
may require that you implement additional ERM so that the NAAQS are not
exceeded.

Sec. 550.307 What ERM are required for a long-term facility?

(a) Control of emissions of VOCs from a long-term facility. If any
long-term facility requires ERM for VOCs under Sec. 550.303(f), you
must propose ERM for the facility. The extent of the ERM required
depends on the attainment status of the State area affected by your
projected emissions.
(1) Except as provided in paragraph (3), if all the State areas
potentially affected by your projected emissions of VOCs are designated
as attainment areas for O3 and PM2.5, then you
must evaluate and propose ERM utilizing the process described for a
short-term facility in Sec. 550.306(a)(1) through (4) and consider all
relevant ERM, excluding BACT. You must demonstrate in your plan that
the ERM you propose, excluding BACT, will reduce the emissions of VOCs
to the lowest practicable and reasonable rate, expressed in tpy. If you
elect to propose BACT in lieu of an alternative ERM, you must provide a
description of the associated energy, environmental, and economic
impacts, and other costs.
(2) Except as provided in paragraph (a)(3) of this section, if your
projected emissions of VOCs potentially affect a State coastal area
designated as a non-attainment area for O3 or
PM2.5, then you must evaluate BACT and other relevant ERM
and propose ERM utilizing the process described for a short-term
facility in Sec. 550.306(a)(1) through (4). You must fully reduce the
projected emissions of VOCs to a level not to exceed the EET for VOCs,
as calculated for your plan in accordance with Sec. 550.303(c). If
your proposed ERM are insufficient to reduce the emissions of VOCs to a
level that does not exceed the EET, you must propose and apply
additional ERM until such reduction is achieved. For any proposed BACT,
you must provide a description of the associated energy, environmental
and economic impacts, and other costs.
(3) VOC waiver: If your projected emissions of VOCs potentially
affect a State coastal area but you can demonstrate that your VOCs will
not cause an increase, or would cause a reduction, in the formation of
O3 (i.e., reduce the O3 production efficiency),
then no ERM are required for those VOCs.
(b) Control of emissions of criteria air pollutants from a long-
term facility. If a long-term facility requires ERM for criteria air
pollutants under Sec. 550.305, then you must propose ERM and conduct
modeling as specified below. The objectives of your proposal, and the
extent to which additional requirements may apply, depend on the
attainment status of the affected State area(s).
(1) If all State areas affected by your emissions are designated as
attainment areas, then:
(i) You must consider all relevant ERM excluding BACT, utilizing
the process described for a short-term facility in Sec. 550.306(a)(1)
through (4).
(ii) You must conduct modeling for all of the air pollutants set
out in the table at 40 CFR 52.21(c) using the reduced projected
emissions that result from your proposed ERM. If photochemical models
are required under Sec. 550.304, then you must also perform
photochemical modeling and add the results of those models to the
results of the subsequent model results.
(iii) You must combine the ambient air concentrations resulting
from the projected emissions of each relevant CP with those emissions
of the same CP from other onshore and offshore sources which contribute
to the consumption of the maximum allowable increases above the
baseline concentration for each pollutant and baseline area as
established in 40 CFR 52.21. Compare your results with the AAIs
applicable to the Class area designation of the State area set out in
table 40 CFR 52.21(c).
(A) For this analysis, use the ambient air quality concentration
data specified in Sec. 550.304(e)(2).

[[Page 19812]]

(B) As an alternative, you may instead model only the increment-
related emissions increases and decreases between the baseline date and
the modeling date (using emissions inventory data) for all relevant
onshore and offshore sources, combined, and then compare the resulting
modeled concentration change to the appropriate increment value,
without regard to ambient background concentrations.
(iv) If your projected emissions affect State areas with multiple
class area designations, then you must reduce your projected emissions
to meet the AAIs set out in the table in 40 CFR 52.21(c), according to
the requirements for each class area.
(v) If your proposed ERM are sufficient to reduce projected
emissions, such that projected concentrations do not exceed any of the
AAIs, you must then conduct the analysis described in Sec.
550.307(b)(1)(vi). If your modeling results exceed the AAIs for any
given air pollutant, then you must continue to apply additional ERM to
sources to reduce that pollutant until additional modeling confirms
that your projected concentrations do not exceed any AAI. Having done
this, you must then conduct the analysis described in Sec.
550.307(b)(1)(vi).
(vi) You must conduct additional modeling, adding the appropriate
background concentrations defined under Sec. 550.302 and specified in
Sec. 550.304(e)(2) to your results, in order to determine the relevant
design concentrations. You must compare the design concentrations for
each criteria air pollutant with the NAAQS set out in 40 CFR part 50.
If any of the NAAQS is exceeded for any air pollutant for any period of
exposure, then you must propose additional ERM, and repeat the
corresponding modeling, until you can demonstrate that your design
concentrations do not exceed the NAAQS.
(2) If your emissions affect any area designated as a non-
attainment area, then you must evaluate BACT and other relevant ERM
utilizing the process described for a short-term facility in Sec.
550.306(a)(1) through (4) and consider all relevant ERM, including
BACT. You must reduce the ambient impact of your emissions of all
criteria air pollutants to a level that does not exceed the applicable
SILs at 40 CFR 51.165(b)(2). You must conduct modeling using your
revised projected emissions and compare the results with the SILs. If
photochemical modeling is required under Sec. 550.304, then you must
also perform additional photochemical modeling and combine the results
of that modeling with the results of the subsequent dispersion models.
If your results exceed any SIL for any criteria air pollutant for any
averaging time, then you must apply additional ERM until additional
modeling demonstrates that all projected emissions have been fully
reduced so that no SIL is exceeded for any criteria air pollutant over
any applicable averaging time. Having done this, you must then conduct
the analysis described in Sec. 550.307(b)(1)(vi).
(c) Exceptions to the ERM requirement: (1) AAIs. For any averaging
time other than an annual period, a facility's projected emissions may
cause an ambient impact that exceeds an applicable AAI one time during
any rolling 12-month period for any given criteria air pollutant at any
one location and still be considered to have fully reduced emissions.
(2) NOX Waiver: If your projected emissions of
NOX potentially affect a State coastal area, but you can
demonstrate that those emissions would not cause an increase, or would
cause a reduction, in the formation of O3 (i.e., reduce the
O3 production efficiency), then no ERM are required for
NOX, unless:
(i) The potentially affected area is an attainment area for
NOX and your analysis indicates that the AAIs for
NOX would be exceeded in the absence of such ERM; or
(ii) The potentially affected area is a non-attainment area for
NOX.
(3) VOC Waiver. A VOCs waiver could apply, as described in Sec.
550.307(a)(3).
(4) Safety exception. If the implementation of a plan under these
regulations would compromise the safety of the operation of the
facility, and such implementation of any air quality standards or
benchmarks cannot be otherwise addressed, then BOEM may waive the
requirement to apply ERM.
(d) NAAQS requirement. No concentration of an air pollutant may
exceed the concentration permitted under any primary or secondary
NAAQS.
(e) Emissions credits. You may propose to use emissions credits to
achieve the equivalent reduction of emissions for any criteria air
pollutant as an alternative to any other ERM, regardless of the
attainment status of the State area affected by your potential
emissions.

Sec. 550.308 Under what circumstances will BOEM require additional
ERM on my proposed facility or facilities?

(a) Regional Supervisor review. You may be required to apply
additional ERM, on either a temporary or permanent basis, depending on
the circumstances, even though you have demonstrated compliance with
the sections above, if BOEM determines that your projected emissions
or, where applicable, complex total emissions, may cause or contribute
to a violation of a NAAQS. The Regional Supervisor may make this
determination based on:
(1) Information submitted by a State or local government, or a
Federally-recognized Indian tribe;
(2) A cumulative impacts analysis conducted for an environmental
impact statement (EIS) prepared to comply with the National
Environmental Policy Act (NEPA);
(3) A compliance review of your proposed plan under Sec.
550.232(b) for an EP, or Sec. 550.267(c) for a DPP or DOCD; or
(4) The declaration by an adjacent State, or the USEPA, of an air
quality emergency for a location that may be affected by air emissions
generated by your operations.
(b) Lessee's or operator's right to challenge. You will be given
notice of the Regional Supervisor's determination, as well as an
opportunity to present additional information and analysis for review
by the Regional Supervisor. If you present the Regional Supervisor with
additional information and analysis, the Regional Supervisor will
reassess whether your projected emissions, or complex total emissions,
may cause or contribute to a violation of any NAAQS, and whether
additional ERM will be required for your facility. The Regional
Supervisor will then notify the State or local government, or
Federally-recognized Indian tribe, and explain the reasons for this
determination.

Sec. 550.309 What requirements apply to my ERM?

(a) Sufficiency. Your proposed ERM must be sufficient to achieve
actual emissions reductions corresponding to those reported in your
plan for the duration of your plan's operations under all reasonably
foreseeable conditions. On a case-by-case basis, the Regional
Supervisor will review your proposed ERM and make a determination
whether such measures meet the applicable criteria.
(b) Effectiveness. You must continually ensure the effectiveness of
your ERM for the duration of your plan's operations. If your measures
become disabled or unavailable, you must immediately notify the
Regional Supervisor and replace such ERM with others of equal or
superior effectiveness within 30 days of discovering the disability or
unavailability, unless the

[[Page 19813]]

Regional Supervisor approves an extension not to exceed 90 days.
(c) Control efficiency. Your proposed ERM must reflect actual ECE.
You must substantiate any ECE that you project and provide sufficient
evidence to justify your ECE to the satisfaction of the Regional
Supervisor.
(1) Should your substantiating data indicate a range of ECE, you
must utilize the more conservative estimates (i.e., those that would
result in lower ECE) in your analysis and modeling.
(2) ECE estimates of 100 percent are generally not acceptable,
except in cases where there is clear and convincing and/or historical
evidence to justify their use.
(d) Emission reductions monitoring. If ERM are contained in your
approved plan, the Regional Supervisor may require that you provide
actual emissions data and/or any other information annually that the
Regional Supervisor deems necessary to verify the effectiveness of your
proposed ERM or their emission control efficiency.
(1) If your plan is approved subject to the application of ERM, you
must ensure that the emissions associated with each emissions source
for which ERM is required complies with the emissions verification
requirements of Sec. 550.311. The Regional Supervisor may require that
you install emissions measurement meters if the Regional Supervisor
determines that such meters are necessary to ensure compliance with
this requirement.
(2) If you propose or are required to install emissions meters or
any other monitoring equipment, you must collect and maintain monthly
logs of the relevant meter or monitoring equipment readings.
(e) Emissions credits. For emissions credits, the following
requirements also apply:
(1) You must acquire your emissions credits from emissions
source(s), either offshore or onshore, that affect the air quality of
the same AQCR.
(2) For a CP, the emissions credits that you propose must provide a
net air quality benefit for the same pollutant; for a precursor
pollutant, any emissions credits that you propose must provide a net
air quality benefit for that CP for which the pollutant is a precursor.
(3) You must demonstrate to the Regional Supervisor that the
emissions credit you propose binds you and any other parties who agree
to lower their emissions.
(4) You must also demonstrate that any emissions reductions will
last for a period of time sufficient to ensure your plan's continued
compliance with the provisions of this subpart. The Regional Supervisor
may periodically require you to certify that the emissions reductions
are still in place.
(5) Any emissions credits must reduce emissions below rates
otherwise required by law;
(6) In addition to BOEM, you must notify the appropriate State air
quality control jurisdiction of your proposal to acquire emissions
offsets and, if necessary, its need to revise the State Implementation
Plan to include the information regarding the emissions offsets you
have acquired. You must provide evidence of such State notification to
BOEM before you commence any operations that rely on the associated
emissions credits.
(7) Emissions credits are allowed in those circumstances where BOEM
can readily verify the historical emissions from the facility to be
used for the emissions credit, and the emissions reduction associated
with the acquired emissions credit.
(8) The approval of an emissions credit will be contingent upon
receipt of proper documentation and will not be granted if such an
emissions credit would require BOEM to engage in ongoing monitoring to
verify continued compliance.
(9) Nothing in these regulations is intended to restrict emissions
credits from being obtained and shared by multiple lessees or
operators.
(f) Emission reduction measure(s) (ERM): Unless otherwise
specified, you may employ any operational control, equipment
replacement(s), BACT, or emissions credit, on either a temporary or
permanent basis, to reduce the amount of emissions that would occur in
the absence of such measures. Any proposed ERM will become a condition
of your plan upon approval and could be required on either a permanent
or temporary basis, depending on the circumstances and location of the
proposed facilities.
(1) In the event that you elect or are required to apply equipment
replacement on a facility as the selected form of ERM, both the method
of replacement and the equipment must comply with all other applicable
federal regulations.
(2) In the event that the equipment being replaced is part of an
MSC subject to USCG regulation, such replacement must be implemented in
such a manner as to comply with USCG regulations.

Sec. 550.310 How will revisions to the ambient air quality standards
and benchmarks (AAQSB) affect my plan?

(a) Review of plans. BOEM will evaluate the air pollutant emissions
data submitted in your plan for compliance with the AAQSB s in effect
on the date your plan is deemed submitted.
(b) Proposed plans. All activities described in initial, revised,
modified, and supplemental plans must comply with the AAQSB in effect
on the date the plan is deemed submitted, except:
(1) If your plan was deemed submitted shortly after the effective
date of a new or revised AAQSB, and you believe the immediate
application of the new or revised AAQSB is impracticable or would
otherwise impose an unreasonable hardship on your proposed operations,
then you may request a deferral from the requirement to comply with the
new or revised standard. The Regional Director will review your request
and may with the concurrence of the Director grant a temporary
deferral, not to exceed two years, from compliance with the new or
revised AAQSB based upon a finding of impracticability or undue
hardship.
(2) Upon a finding that noncompliance with a new or revised AAQSB
would not significantly affect the air quality of any State, the
Director may grant a departure from compliance with the revised AAQSB.
The Director may condition the departure upon any requirement(s) deemed
necessary to avoid causing or contributing to a violation of the NAAQS.
(c) Approved plans. (1) In order to ensure that your emissions
remain compliant with any changes to the NAAQS, you are required to
resubmit your plan for a periodic air quality review ten years after
BOEM's previous approval of your plan, as further defined in paragraph
(c)(2) of this section. A plan resubmitted pursuant to this provision
must be updated to comply with the requirements of Sec. 550.205 as
they exist at the time of the plan resubmission, including the most
current data on emissions factors and MSC emissions, and must be
reevaluated against the EETs and formulas as they exist at the time of
the plan resubmission. When you resubmit a plan under this provision,
that plan must include estimates for the annual projected emissions for
the subsequent ten years, or for however long the plan's facility or
facilities would be expected to remain in operation, whichever is
shorter. With respect to the emissions calculations for any given
emissions source, the resubmitted plan must account for the most recent
available data on the actual emissions of the relevant emission source.
All of the applicable requirements of this subpart in effect on the
date of resubmission apply on the same basis to a resubmitted plan as
for an initial plan.

[[Page 19814]]

(2) In order to ensure that your emissions remain compliant with
OCSLA, starting in 2020, BOEM will conduct periodic reviews of plans
approved prior to the effective date of the new exemption thresholds.
To accomplish this, from that year forward, you must submit the air
quality component of your previously approved plan according to the
following schedule, regardless of whether you have a change in
emissions.

------------------------------------------------------------------------
Year in which resubmission
Year the plan was approved is required
------------------------------------------------------------------------
Prior to 1980............................. 2020.
1980 through 1984......................... 2021.
1985 through 1989......................... 2022.
1990 through 1994......................... 2023.
1995 through 1999......................... 2024.
2000 through 2004......................... 2025.
2005 through 2009......................... 2026.
2010 through 2012......................... 2027.
2013 through 2014......................... 2028.
2015 through 2016......................... 2029.
2017 through 2018......................... 2030.
2019 through 2020......................... 2031.
2021 through 2022......................... 2032.
2023 and beyond........................... Ten years after year of
approval.
------------------------------------------------------------------------

(i) The plan is due to BOEM on the same month as the month in which
the plan was originally approved.
(ii) For an initially approved plan, the lessee or operator is
required to resubmit the plan in accordance with the table in paragraph
(c)(2) of this section.
(iii) If a revised, modified, resubmitted, or supplemental plan is
submitted within ten years from the date of the initial plan submittal,
the new resubmission date would be ten years from the date of approval
of the revised, modified, resubmitted, or supplemental plan.
(iv) If you fail to submit a revised plan as required under this
section, then the previous approval of your plan is revoked. You may be
subject to civil penalties or other appropriate sanctions for a
regulatory violation, including the requirement to cease operations, as
provided by 43 U.S.C. 1350.

Sec. 550.311 Under what circumstances will I be required to measure
and report my actual emissions?

(a) Compliance demonstration conditions. Under any of the following
conditions, you must demonstrate that your actual emissions have at all
times and continue to be in compliance with your previously approved
plan:
(1) Your plan is approved subject to the implementation of BACT or
emissions credits;
(2) Any emission source on your facility uses an engine that is not
certified by the USEPA consistent with the requirements of 40 CFR 1042
or 40 CFR 1043, for U.S.-flag vessels, or that is not certified to the
MARPOL Annex VI Regulation 13 requirements as required by the Act to
Prevent Pollution from Ships, for foreign-flag vessels operating in the
U.S.
(3) The Regional Supervisor determines that your projected
emissions, or complex total emissions, for any criteria or precursor
air pollutant, calculated on either an annual basis or on the basis of
a 12-month rolling sum, may significantly underestimate your actual
emissions based either on historical data about your emissions sources
or on ambient air monitoring.
(4) BOEM determines that your facility causes or contributes to an
exceedance of the NAAQS in any State.
(b) Emissions reporting requirements.If you are required to make
the demonstration described in this section:
(1) Your measurement of actual emissions must include enough of
your emissions sources to ensure that the actual emissions associated
with facilities and MSCs operating under your approved plan are
consistent with the projected emissions approved for your plan. You
must consider every source that was included in your approved plan in
addition to any source that would be classified as part of your
projected emissions if your plan were resubmitted under the current
regulations.
(2) BOEM will consider various alternatives for reporting of
relevant emissions sources. One option would be to monitor only the
following key pieces of equipment:
(i) For facilities, the required monitoring and reporting of
engines would typically include:
(A) Onboard facility engines;
(B) Power generation engines;
(C) Hydraulic power units (HPU) engines;
(D) Deck cranes;
(E) Cementing units;
(F) Engines with a maximum power rating exceeding 200 hp (149 kW).
(ii) For facilities, monitoring and reporting would typically
exclude:
(A) Propulsion engines;
(B) Boilers and incinerators;
(C) Emergency generators;
(D) Lifeboat engines.
(iii) For MSCs the sources, monitoring and reporting would likely
include:
(A) Propulsion engines;
(B) Power generation engines;
(C) Marine auxiliary engines; or,
(D) Engines with a maximum power rating exceeding 200 hp (149 kW).
(iv) MSCs monitoring and reporting would typically exclude boilers
and incinerators, emergency generators, and any engines onboard science
vessels, OSVs, or lifeboats.
(3) Your demonstration must reflect your actual operations on the
OCS and must be based exclusively on data derived from your actual
equipment and not only on the basis of ECEs or fuel logs or activity
data.
(4) You must be able to demonstrate that the data submitted to BOEM
under this section is consistent with any data provided to BOEM under
the requirements of Sec. 550.187.
(5) You must provide the information required for this
demonstration in a manner and on a schedule determined by the Regional
Supervisor.
(c) Notification requirements. If, on the basis of your
demonstration of actual emissions, you determine at any time your
actual emissions exceed your projected emissions for any pollutant you
must notify BOEM and provide BOEM with the appropriate data regarding
the exceedance.
(d) Data submittal requirements. You must submit data and
information in a format, and using the forms as specified by BOEM. You
must submit information in an electronically-readable format, unless
otherwise directed by the Regional Supervisor. If you transmit the
information to BOEM electronically, you must use a delivery medium or
transmission method authorized by BOEM.

Sec. 550.312 What post-approval recordkeeping and reporting is
required?

(a) Stack testing. If stack testing was used as a method to develop
your emissions factors under Sec. 550.205 or was used to develop any
of the other information submitted pursuant to that section, then you
must conduct the stack testing every three years and report the
results, utilizing the General Provisions for Determining Standards of
Performance for New Stationary Sources, Available at 40 CFR 60.8.
(b) Fuel logs and activity data. In order to demonstrate compliance
with your plan, you must retain information on monthly fuel
consumption, for each emissions source, including attributed emissions
sources, showing the quantity, type, and sulphur content of fuel used;
collect facility and equipment usage information, including hours of
operation at each percent of capacity for each emissions source.
Venting, flaring, flashing and any other release of any air pollutant
emissions that would not otherwise be accounted for by fuel consumption
must be reported for any emissions source that generates criteria

[[Page 19815]]

air pollutants or precursor air pollutants in connection with OCS
activities.
(1) You must retain this information for a period of no less than
ten years. You must submit this information to BOEM on a schedule set
by the Regional Director.
(2) If BOEM obtains the relevant data for your attributed emissions
from an independent third party, then the Regional Supervisor may waive
the requirement to submit fuel logs or collect facility and equipment
usage information for MSCs.
(3) Electronic Records. Record-keeping and reporting must be
consistent with the USEPA's requirements for electronic reporting and
recordkeeping requirements for new source performance standards.
(c) Meteorological reporting. The Regional Supervisor may require,
for a period of time and in a manner approved or prescribed, that you
collect and report meteorological data from any of your facilities. The
Regional Supervisor may allow you to substitute facility-specific data
for meteorological data derived from any other mutually agreed upon
location.
(d) Other information. Notwithstanding any other provision within
this subpart, the Regional Supervisor may require you to provide any
other information within your possession, or otherwise reasonably
obtainable, to support any finding or determination under this subpart.
(e) Additional requirements imposed by other agencies. None of the
provisions of this section would prevent the imposition of additional
monitoring or reporting requirements on the part of BSEE or any other
federal agency.

Sec. 550.313 Under what circumstances will BOEM impose additional
requirements on facilities operating under already approved plans?

(a) BOEM may impose additional air quality requirements on
facilities operating under already approved plans if an applicable
AAQSB changes or if BOEM determines:
(1) Your operations are causing or contributing to a violation of
the NAAQS, either individually or in combination with any other
offshore operations;
(2) Your plan was approved with either a NOX waiver or a
VOC wavier, and the air quality conditions in the affected State have
changed to such an extent that your emissions of NOX or VOCs
would contribute to an increase in the ambient O3
concentration such that the NAAQS for O3 may be exceeded (in
an attainment area), or the NAAQS for O3 would continue to
be exceeded (in an area that is non-attainment for O3).
(3) Your plan was approved with a NOX waiver, and the
air quality conditions in the affected State have changed to such an
extent that your emissions of NOX would contribute to an
increase in the ambient concentration of NOX such that the
NAAQS for NOX may be exceeded (in an attainment area), or
the NAAQS for NOX would continue to be exceeded (in an area
that is non-attainment for NOX).
(4) Your operation is emitting unauthorized air pollutants;
(5) Your operation is creating conditions posing an unreasonable
risk to public health or welfare; or
(6) Your operation is violating any applicable federal, State or
tribal law related to air quality.
(b) If a plan was approved for a short-term facility that becomes a
long-term facility, a new air quality plan must be submitted for the
facility under the standards applicable to a long-term facility. If
this reclassification resulted from adverse weather conditions, or
other circumstances beyond your control, that prevented operations in
your lease area, the Regional Director may grant a temporary exception
for a period not to exceed the number of months that you were unable to
operate.

Sec. 550.314 Under what circumstances will the Regional Supervisor
review the projected emissions from my existing facility or facilities?

(a) A State, or a Federally-recognized Indian tribe, may request
the Regional Supervisor to supply it with the air pollution data
regarding an existing facility's projected emissions, when such data
are needed either for the updating of the State's emissions inventory
or because a State believes an existing facility's projected emissions
may cause or contribute to a violation of the NAAQS.
(b) The Regional Supervisor may require you to submit air pollutant
emissions data to the State, or a Federally-recognized Indian tribe,
submitting such a request.
(c) The State, or a Federally-recognized Indian tribe, submitting a
request may submit information to BOEM that it believes indicates
projected emissions from an existing facility may cause or contribute
to a violation of the NAAQS. You will be given the opportunity to
present information to the Regional Supervisor that demonstrates that
your facility's projected emissions do not cause such an effect.
(d) The Regional Supervisor will evaluate the new information
submitted and will determine, based on the emissions data, the
available meteorological data, and the distance of the facility from
the SSB whether your actual emissions, including your attributed
emissions, has the potential to cause or contribute to a violation of
the NAAQS.
(1) If the Regional Supervisor determines that your existing
facility's projected emissions are unlikely to cause or contribute to a
violation of the NAAQS, the Regional Supervisor will notify the
requesting State, or a Federally-recognized Indian tribe, and you and
explain the reasons for this finding.
(2) If the Regional Supervisor determines that your existing
facility's projected emissions have the potential to cause or
contribute to a violation of the NAAQS, you must submit the additional
information that the Regional Supervisor requests in order for BOEM to
determine whether or not your existing facility causes or contributes
to a violation of the NAAQS. You must submit this information within
120 days of the Regional Supervisor's request, or within a longer
period of time at the Regional Supervisor's discretion.
0
26. Add Sec. 550.1012 to subpart J to read as follows:

Sec. 550.1012 What are the air quality requirements for pipeline
rights-of-way holders?

(a) When you apply for or acquire a ROW in any part of the OCS
under the air quality regulatory jurisdiction of the Department, you
must:
(1) Include in your application the information required by Sec.
550.205; and
(2) Demonstrate that your activities will comply with the
requirements of subpart C of this part.
(b) For the purpose of this section:
(1) Any requirement in either Sec. 550.205 or subpart C of this
part that refers to plans should be interpreted to apply equally to ROW
applications except for the provision regarding the consolidation of
multiple facilities (Sec. 550.303(d)) and for the periodic
resubmission of plans (Sec. 550.310(c));
(2) Any requirement in either Sec. 550.205 or subpart C of this
part that refers to lessees or operators applies equally to ROW holders
or grantees, except that no additional requirements apply to any
proposed or existing pipeline ROW or lease term pipeline holders, that
are already included within the scope of an existing or proposed
exploration or development plan.
(3) BOEM will notify BSEE of its determination that you have
provided the information required by Sec. 550.205 and met the
requirements of subpart C of this part. If necessary, BOEM will

[[Page 19816]]

notify BSEE of additional conditions necessary to ensure that your
activities will comply with subpart C of this part.

[FR Doc. 2016-06310 Filed 4-4-16; 8:45 am]
BILLING CODE 4310-MR-P

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