# Southern Ute Indian Tribe (2024) > Briefs, arguments, decisions, and more. URL: https://www.frixlaw.com/law-library/documents/tribal%3Asouthern_ute%3A0de6875756e1d6b3 ## Record - **Collection:** Tribal code - **Document type:** Tribal code ## Text Southern Ute Indian Tribe Air Quality Division Title V Operating Permit Southern Ute Indian Tribe Environmental Programs Department Air Quality Division 71 Mike Frost Way Ignacio, Colorado 81137 AIR POLLUTION CONTROL TITLE V PERMIT TO OPERATE In accordance with the provisions of Title V of the Clean Air Act (42 U.S.C. 7661-7661f) and Part 1, Article II of the Southern Ute Indian Tribe/State of Colorado Environmental Commission’s Reservation Air Code (RAC) and applicable rules and regulations, Red Cedar Gathering Company Trail Canyon Compressor Station is authorized to operate air emission units and to conduct other air pollutant emitting activities in accordance with the conditions listed in this permit. This source is authorized to operate at the following location: Southern Ute Indian Reservation Section 1, T32N, R9W La Plata County, Colorado Terms not otherwise defined in this permit have the meaning assigned to them in the referenced regulations. All terms and conditions of the permit are enforceable by the Tribe and citizens under the Clean Air Act. Daniel Powers, Air Quality Division Head Environmental Programs Department Southern Ute Indian Tribe AIR POLLUTION CONTROL TITLE V PERMIT TO OPERATE Red Cedar Gathering Company Trail Canyon Compressor Station SUIT Account Identification Code: 2-027 Permit Number: V-SUIT-0048-2024.01 [Replaces Permit No.: V-SUIT-0048-2024.00] Initial Issue Date: Revised Date: Expiration Date: July 21, 2025 September 9, 2025 July 21, 2030 The SUIT account identification code and permit number cited above should be referenced in future correspondence regarding this facility. Permit Issuance History DATE TYPE OF ACTION DESCRIPTION OF ACTION PERMIT NUMBER September 2009 Permit Issued Initial Part 71 Permit Issued # V-SU-0048-08.00 October 2009 Permit Revision Administrative Amendment # V-SU-0048-08.01 February 2011 Reopen for Cause May 2012 Permit Revision Minor Modification # V-SU-0048-2008.03 January 2014 Permit Issued Initial Part 70 Permit Issued Replaces EPA-Issued Permit: V-SU-0048-2008.03 # V-SUIT-0048-2014.00 September 2014 Permit Revision Administrative Amendment # V-SUIT-0048-2014.01 August 12, 2019 # V-SU-0048-2008.02 st Permit Renewal 1 Part 70 Permit Renewal # V-SUIT-0048-2019.00 February 13, 2023 Permit Revision Minor Permit Revision Added compressor engine C206 updated affected units for 40 CFR 60, Subpart OOOOa.  Updated C-205 engine serial number and installation date.  Updated Quad Z performance testing language. # V-SUIT-0048-2019.01 July 21, 2025 Permit Renewal 2nd Part 70 Permit Renewal # V-SUIT-0048-2024.00 Administrative Revision Added language to 40 CFR 60, Subpart OOOOb, due to the 2025 EPA Final Interim Rule extending compliance deadlines for 40 CFR 60, Subpart OOOO/a/b/c. # V-SUIT-0048-2024.01   September 9, 2025 Permit Revision Table of Contents Abbreviations and Acronyms ................................................................................................................................. 3 Section I – Source Information and Emission Unit Identification ............................................................................ 6 Source Information ..........................................................................................................................................6 Source Emission Points ....................................................................................................................................7 Section II – General Requirements ......................................................................................................................... 8 Title V Administrative Requirements ...............................................................................................................8 1.1. Annual Fee Payment [RAC 2-110(1)(h) and RAC 2-118] ........................................................................ 8 1.2. Compliance Requirements .................................................................................................................. 10 1.3. Duty to Provide and Supplement Information [RAC 2-110(7)(e), 2-106(5), and 2-124] ....................11 1.4. Submissions [RAC 2-105] .....................................................................................................................12 1.5. Severability Clause [RAC 1-106 and RAC 2-110(1)(f)] .........................................................................12 1.6. Permit Actions [RAC 2-110(3)] ............................................................................................................ 12 1.7. Administrative Permit Revision [RAC 2-111(2)] .................................................................................13 1.8. Minor Permit Revisions [RAC 2-111(3)] ..............................................................................................13 1.9. Significant Permit Revisions [RAC 2-111(4)] .......................................................................................14 1.10. Permit Reopenings, Revocations and Reissuances, and Terminations [RAC 2-112] .........................14 1.11. Property Rights [RAC 2-110(3)(e)] .......................................................................................................16 1.12. Inspection and Entry [RAC 2-110(9)(b)] ..............................................................................................16 1.13. [Reserved] ............................................................................................................................................16 1.14. Permit Transfers [RAC 2-113] ..............................................................................................................16 1.15. Off-Permit Changes [RAC 2-116(2)]..................................................................................................... 16 1.16. Permit Expiration and Renewal ..........................................................................................................17 Facility-Wide Requirements...........................................................................................................................18 2.1. General Recordkeeping Requirements [RAC 2-110(6)] ...................................................................... 18 2.2. General Reporting Requirements .......................................................................................................19 2.3. Alternative Operating Scenarios [RAC 2-110(8)] ................................................................................20 2.4. Permit Shield [RAC 2-110(10)(c)].........................................................................................................22 2.5. Stratospheric Ozone and Climate Protection [40 CFR Part 82] ..........................................................22 Section III – Site Specific Permit Terms ................................................................................................................ 23 New Source Performance Standards (NSPS) and 40 CFR Part 60 ..................................................................23 1.1. 40 CFR Part 60, Subpart OOOOb – Standards of Performance for Crude Oil and Natural Gas Facilities for Which Construction, Modification or Reconstruction Commenced After December 6, 2022 [40 CFR 60.5360b - 60.5439b] ..................................................................................................................................23 National Emission Standards for Hazardous Air Pollutants (NESHAP) and 40 CFR Part 63 ...........................51 2.1. 40 CFR Part 63, Subpart HH – National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities [40 CFR 63.760 – 63.779, RAC 4-103] ...................................................51 2.2. 40 CFR Part 63, Subpart ZZZZ – National Emission Standards for Hazardous Air Pollutants from Oil and Natural Gas Production Facilities [40 CFR §63.6580 – 63.6675 and RAC §4-103] .....................................62 Reserved – Tribal Minor New Source Review ................................................................................................86 1 3.1 Federal Implementation Plan for Managing Air Emissions from True Minor Sources in Indian Country in the Oil and Natural Gas Production and Natural Gas Processing Segments of the Oil and Natural Gas Sector [40 CFR 49.101-49.105] [SU-000048]...............................................................................................86 Reserved – Prevention of Significant Deterioration Requirements ............................................................... 86 Reserved – Consent Decree Requirements ....................................................................................................86 Reserved – Compliance Assurance Monitoring (CAM) Requirements ...........................................................86 Enhanced Monitoring, Recordkeeping, and Reporting..................................................................................86 Section IV – Appendix .......................................................................................................................................... 88 Inspection Information ..................................................................................................................................88 1.1. Driving Directions: ...............................................................................................................................88 1.2. Global Positioning System (GPS): .......................................................................................................88 1.3. Safety Considerations: ........................................................................................................................88 2 Abbreviations and Acronyms 4SLB 4SRB AFS AQD bbl BACT CAA CAM CEMS CFR CMS COMS CO CO2 dscf dscm EPA gal GPM H 2S HAP hr ID kg lbs MACT Mg MMBtu MMSCFD mo NESHAP NMHC NOx NSPS NSR pH PM PM10 ppbvd ppm ppmvd PSD PTE psi psia RAC RICE RMP scf scfm SI SO2 SUIT tpy Tribe Four-Stroke Lean-Burn Four-Stroke Rich-Burn Air Facility System database Southern Ute Indian Tribe’s Air Quality Division Barrels Best Available Control Technology Clean Air Act [42 U.S.C. Section 7401 et seq.] Compliance Assurance Monitoring Continuous Emission Monitoring System Code of Federal Regulations Continuous Monitoring System (includes COMS, CEMS and diluent monitoring) Continuous Opacity Monitoring System Carbon monoxide Carbon dioxide Dry standard cubic foot Dry standard cubic meter United States Environmental Protection Agency Gallon Gallons per minute Hydrogen sulfide Hazardous Air Pollutant Hour Identification Number Kilogram Pounds Maximum Achievable Control Technology Megagram Million British Thermal Units Million standard cubic feet per day Month National Emission Standards for Hazardous Air Pollutants Non-methane hydrocarbons Nitrogen Oxides New Source Performance Standard New Source Review Negative logarithm of effective hydrogen ion concentration (acidity) Particulate Matter Particulate matter less than 10 microns in diameter Parts per billion by volume, dry Parts per million Parts per million by volume, dry Prevention of Significant Deterioration Potential to Emit Pounds per square inch Pounds per square inch absolute Southern Ute Indian Tribe/State of Colorado Environmental Commission’s Reservation Air Code Reciprocating Internal Combustion Engine Risk Management Plan Standard cubic feet Standard cubic feet per minute Spark Ignition Sulfur Dioxide Southern Ute Indian Tribe Ton(s) Per Year Southern Ute Indian Tribe 3 US EPA VOC United States Environmental Protection Agency Volatile Organic Compounds 4 Table of Figures Table 1 - Emission Units................................................................................................................. 7 Table 2 - Insignificant Emission Units ........................................................................................... 7 5 Section I – Source Information and Emission Unit Identification Source Information Owner Name: Red Cedar Gathering Company Facility Name: Trail Canyon Compressor Station Facility Location: Section 1, T32N, R9W Latitude: 37.049720 °N Longitude: State: -107.781940 °W Colorado County: La Plata Responsible Official: President – Chief Operating Officer SIC Code: 1311 ICIS Identification Number: SU00000008067U0021 EPA Facility Registry ID: 110063859267 Other Clean Air Act Permits Federal Implementation Plan: # SU-000048 Process Description: The Trail Canyon Compressor Station, owned and operated by Red Cedar Gathering Company, is located in Southwestern Colorado within the exterior boundaries of the Southern Ute Indian Reservation. Trail Canyon is a production field facility prior to the point of custody transfer. Natural gas product is provided to Trail Canyon from several upstream wells and compression stations. Current Configuration: Units C-204 and C-205 pull gas from the low-pressure pipelines at approximately 30psi and compress the gas to approximately 350psi. The gas is then processed through the dehy unit and discharged into Red Cedar’s mid-pressure pipeline. Under this configuration, the station can process 10-12 Mscf/day. Units C-201, C-202, and C-206 boost 5060 MMscf/day of high-pressure gas, from various compressor facilities, from roughly 800psi to a discharge pressure around 1,000psi. The gas is discharged to a high-pressure valve set known as the Val Verde Valve set. The gas that is processed through units C-201 and C-202 is not dehydrated at the Trail Canyon Compressor Station. The facility does not extract natural gas liquids from field gas nor fractionate mixed NGL’s to natural gas products. The facility has storage vessels, but none with the potential for flash emissions. Trail Canyon’s primary emitters consist of 5 compressor engines and one glycol dehydration unit. The facility has several heaters, and tanks that qualify as insignificant emission units. Trail Canyon does not engage in pigging operations. The 5 compressor engines are 4SLB SI RICE. One of these compressor engines (C-204) is subject to 40 CFR 63 Subpart ZZZZ regulations. Red Cedar has selected oxidation catalyst as the means to satisfy the regulatory requirements for Carbon Monoxide (CO) reduction. 6 Source Emission Points Table 1 - Emission Units Emission Unit ID Control Equipment Description Caterpillar G3516LE (4SLB SI) Natural Gas-Fired Compressor Engine 1,150 Name Plate Rated HP C-201 Serial No. 4EK01712 Install Date: 06/10/2025 C-202 Serial No. 4EK02752 Install Date: 07/07/2009 C-206 Serial No. 4EK02291 Install Date: 11/19/2024 None Caterpillar G3516LE (4SLB SI) Natural Gas-Fired Compressor Engine 1,342 Name Plate Rated HP C-204 Serial No. 4EK04171 Install Date: Miratech Oxidation Catalyst with AFRC 03/24/2025 Waukesha 7042GL (4SLB SI) Natural Gas-Fired Compressor Engine 1,377 Name Plate Rated HP C-205 Serial No. C-12572/4 Install Date: None 12/21/2022 PESCO Tri-Ethylene Glycol (TEG) Dehydrator 25 (MMscf/day) None X-303 Serial No. N/A Install Date: 05/06/2009 Table 2 - Insignificant Emission Units Emission Unit ID Amount Description Size Units X-303a H-101, 102 H-501, 502 H-603, 701, 702 TK-501 TK-502 TK-503 TK-505, 512, 513, 521 TK-506 TK-508, 509 TK-514 TK-515, 516 TK-517, 518 TK-601 TK-602 FUG 1 2 2 3 1 1 1 4 1 2 1 2 2 1 1 N/A TEG Reboiler Catalytic Heater Tank Heater Catalytic Heater Waste Water Drain Tank Waste Oil Drain Tank Glycol Still Vent Tank Engine Coolant Makeup Tank Engine Lube Oil Makeup Tank Compressor Lube Oil Makeup Tank Compressor Lube Oil Tank Compressor Oil Day Tank Engine Oil Day Tank Glycol Makeup (Storage) Tank TEG Stock Tank Fugitive Emissions 0.65 0.10 0.325 0.005 15,750 6,615 788 500 500 500 500 55 55 500 375 N/A MMBtu/hr MMBtu/hr MMBtu/hr MMBtu/hr Gallons Gallons Gallons Gallons Gallons Gallons Gallons Gallons Gallons Gallons Gallons Gallons 7 Section II – General Requirements Title V Administrative Requirements 1.1. Annual Fee Payment [RAC 2-110(1)(h) and RAC 2-118] 1.1.1. An annual operating permit emission fee shall be paid to the Tribe by the permittee. [RAC 2-118(2)] 1.1.2. The permittee shall pay the annual permit fee each year no later than April 1 st for the preceding calendar year. [RAC 2-118(2)] 1.1.3. Fee payments shall be remitted in the form of a money order, bank draft, certified check, corporate check, or electronic funds transfer payable to the Southern Ute Indian Tribe and sent or delivered by the United States Postal Service c/o Environmental Programs Department Part 70 Program, P.O. Box 737 MS #84, Ignacio, Colorado 81137; or by common carrier (such as UPS or FedEx) c/o Environmental Programs Department Part 70 Program, 398 Ouray Drive, Ignacio, Colorado 81137. [RAC 2-118(4)(a)] 1.1.4. The permittee shall send an updated fee calculation worksheet submitted annually by the same deadline as required for fee payment to the address listed in the Submissions section of this permit. [RAC 2-118] 1.1.5. The permittee shall submit the initial fee calculation work sheet using the most recent form provided by the Tribe. [RAC 2-118(2)(c)] 1.1.6. Basis for calculating annual fee: 1.1.6.1. Subtotal annual fees shall be calculated by multiplying the applicable emission fee set pursuant to RAC §2-119(1) of this code times the total tons of actual emissions for each fee pollutant. In lieu of actual emissions, annual fees may be calculated based on the potential to emit for each fee pollutant. Emissions of any regulated air pollutant that already are included in the fee calculation under a category of regulated pollutant, such as a federally listed hazardous air pollutant that is already accounted for as a VOC or as PM10, shall be counted only once in determining the source’s actual emissions. [RAC 2-119(2)(a)] 8 1.1.6.1.1. “Actual emissions” means the actual rate of emissions in tpy of any fee pollutant (for fee calculation) emitted from a Title V source over the preceding calendar year or any other period determined by the Tribe to be more representative of normal operation and consistent with the fee schedule adopted by the Tribe and approved by the Administrator. Actual emissions shall be calculated using each emissions units actual operating hours, production rates, in-place control equipment, and types of materials processed, stored, or combusted during the preceding calendar year or other period used for this calculation. [RAC 1-103(2)] 1.1.6.1.2. Actual emissions shall be computed using compliance methods required by the permit. [RAC 2-118(1)(b)] 1.1.6.1.3. If actual emissions cannot be determined using the compliance methods in the permit, the permittee shall use other federally recognized procedures. [RAC 2-118(1)(b)] 1.1.6.2. The total annual fee submitted shall be the greater of the applicable minimum fee or the sum of subtotal annual fees for all fee pollutants emitted from the source. [RAC 2-119(2)(b)] [Explanatory note: The applicable emission fee amount and applicable minimum fee (if necessary) are revised each calendar year to account for inflation, and they are available from AQD prior to the start of each calendar year.] 1.1.6.3. The permittee shall exclude the following emissions from the calculation of fees: 1.1.6.3.1. The amount of actual emissions of any one fee pollutant that the source emits in excess of 4,000 tpy. 1.1.6.3.2. Any emissions that come from insignificant activities not required in a permit application pursuant to RAC §2-106(4). [RAC 1-103(2)(c)] 1.1.7. Annual fee calculation worksheets shall be certified as to truth, accuracy, and completeness by a responsible official. [RAC 2-105 and RAC 2-118(2)(c)] 9 1.1.8. Failure of the permittee to pay fees by the due date shall subject the permittee to assessment of penalties and interest in accordance with RAC §2-118(6). [RAC 2-118(6)] 1.1.9. When notified by the Tribe of underpayment of fees, the permittee shall remit full payment within 30 days of receipt of an invoice from the Tribe. [RAC 2-119(3)(b)] 1.1.10. A permittee who thinks a Tribe assessed fee is in error and who wishes to challenge such fee shall provide a written explanation of the alleged error to the Tribe along with full payment of the assessed fee. [RAC 2-119(3)(c)] 1.2. Compliance Requirements 1.2.1. Compliance with the Permit 1.2.1.1. The permittee must comply with all conditions of this part 70 permit. Any permit noncompliance with federally enforceable or Commission-only permit conditions constitutes a violation of the RAC and Clean Air Act and is grounds for enforcement action; for permit termination, revocation and reissuance, or revision; or for denial of a permit renewal application. [RAC 2-110(3)(a)] 1.2.1.2. It shall not be a defense for a permittee in an enforcement action that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of this permit. [RAC 2-110(3)(b)] 1.2.1.3. All terms and conditions of this permit which are required under the Clean Air Act or under any of its applicable requirements, including any provisions designed to limit a source’s potential to emit, are enforceable by the Administrator and citizens under the Clean Air Act, except terms and conditions the permit specifically designates as not being federally enforceable under the Clean Air Act that are not required under the Clean Air Act or under any of its applicable requirements. Terms and conditions so designated are not subject to the requirements of RAC §§2-108, 2-111, 2-112, other than those contained in this paragraph. [RAC 2-110(3)(f)] 1.2.1.4. This permit, or the filing or approval of a compliance plan, does not relieve any person from civil or criminal liability for failure to comply with the provisions of the RAC and the Clean Air Act, applicable regulations thereunder, and any other applicable law or regulation. [RAC 2-110(3)(g)] 10 1.2.1.5. For the purpose of submitting compliance certifications in accordance with the Compliance Certifications condition below of this permit, or establishing whether or not a person has violated or is in violation of any requirement of this permit, nothing shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. [Section 113(a) and 113(e)(1) of the Act, 40 CFR §§51.212, 52.12, 52.33, 60.11(g), and 61.12] 1.2.2. Compliance Certifications 1.2.2.1. The permittee shall submit to the Tribe and the Administrator an annual certification of compliance which shall certify the source’s compliance status with all permit terms and conditions and all applicable requirements relevant to the source, including those related to emission limitations, standards, or work practices. The compliance certification shall be certified as to truth, accuracy, and completeness by a responsible official consistent with RAC §2-110(9)(a). The certification of compliance shall be submitted annually by April 1st and shall cover the preceding calendar year in which the certification of compliance is due, except that the first annual certification of compliance will cover the period from the issuance date of this permit through December 31st of the same year. [RAC 2-110(9)(c)] 1.2.3. Compliance Schedule 1.2.3.1. For applicable requirements with which the source is in compliance, the source will continue to comply with such requirements. [RAC 2-106(4)(l)(ii)] 1.2.3.2. For applicable requirements that will become effective during the permit term, the source shall meet such requirements on a timely basis. [RAC 2-106(4)(l)(iii)] 1.3. Duty to Provide and Supplement Information [RAC 2-110(7)(e), 2-106(5), and 2124] 1.3.1. The permittee shall furnish to the Tribe, within the period specified by the Tribe, any information that the Tribe request in writing to determine whether cause exists for reopening and revising, revoking, and reissuing, or terminating the permit, or to determine compliance with the permit. Upon request, the permittee shall also furnish to the Tribe copies of records that are required to be kept by the permit, including information claimed to be confidential. Information claimed to 11 be confidential must be accompanied by a claim of confidentiality according to the provisions of RAC 2-124. [RAC 2-110(7)(e) and RAC 2-124] 1.3.2. The permittee, upon becoming aware that any relevant facts were omitted or incorrect information was submitted in the permit application or in a supplemental submittal, shall promptly submit such supplementary facts or corrected information. In addition, a permittee shall provide additional information as necessary to address any requirements that become applicable after the date a complete application is filed, but prior to release of a draft permit. [RAC 2-106(5)] 1.4. Submissions [RAC 2-105] 1.4.1. Any application, form, report, compliance certification, or other document submitted by the permittee under this permit shall contain a certification by a responsible official of truth, accuracy, and completeness. This certification shall state that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete. [Explanatory Note: The Tribe has developed a reporting form “CTAC” for certifying truth, accuracy and completeness of part 70 submissions. The form may be found on the AQD’s website (http://www.southernute-nsn.gov/environmental-programs/air-quality).] 1.4.2. Except where otherwise noted, any documents required to be submitted under this permit, including reports, test data, monitoring data, notifications, compliance certifications, fee calculation worksheets, and applications for renewals and permit modifications shall be submitted: 1.5. Severability Clause [RAC 1-106 and RAC 2-110(1)(f)] by email at: airquality@southernute-nsn.gov or by United States Postal Service: Part 70 Program Environmental Programs Department Air Quality Division P.O. Box 737 MS #84 Ignacio, Colorado 81137 or by Common Carrier: Part 70 Program Environmental Programs Department Air Quality Division 398 Ouray Drive Ignacio, CO 81137 The provisions of this permit are severable, and in the event of any challenge to any portion of this permit, or if any provision is held invalid, the remaining permit conditions shall remain valid and in force. 1.6. Permit Actions [RAC 2-110(3)] 12 1.6.1. This permit may be modified, reopened and revised, revoked and reissued, or terminated for cause. [RAC 2-110(3)(c)] 1.6.2. The filing by the permittee of a request for a permit revision, reissuance, or termination, or of a notification of planned changes or anticipated noncompliance shall not stay any permit condition. [RAC 2-110(3)(d)] 1.7. Administrative Permit Revision [RAC 2-111(2)] 1.7.1. The permittee may submit an application for an administrative permit revision as defined in RAC §1-103. [RAC 2-111(2)(a)] 1.7.2. The permittee may implement an administrative permit revision immediately upon submittal of the request for the administrative revision. [RAC 2-111(2)(c)] [Note to permittee: If the provisions allowing for an administrative permit revision do not apply, please contact the Air Quality Division for a determination of similarity prior to submitting your request for an administrative permit revision.] 1.8. Minor Permit Revisions [RAC 2-111(3)] 1.8.1. The permittee may submit an application for a minor permit revision as defined in RAC §1-103. 1.8.2. An application requesting the use of minor permit revision procedures shall meet the requirements of RAC §2-106(4) and shall include the following: 1.8.2.1. A description of the change, the emissions resulting from the change, and any new applicable requirements that will apply if the change occurs; 1.8.2.2. If changes are requested to the permit language, the permittee’s suggested draft permit changes; 1.8.2.3. Certification by a responsible official, consistent with RAC §2-105, that the proposed revision meets the criteria for use of minor permit revision procedures and a request that such procedures be used; and 1.8.2.4. Completed forms for the Tribe to use to notify the Administrator and affected programs as required under RAC §2-108. 13 1.8.2.5. If the requested permit revision would affect existing compliance plans or schedules, related progress reports, or certification of compliance requirements, and an outline of such effects. [RAC 2-111(3)(a)] 1.8.3. The permittee shall not submit multiple minor permit revision applications that may conceal a larger revision that would not constitute a minor permit revision. [RAC 2-111(3)(b)] 1.8.4. The permittee may make the change proposed in its minor permit revision application immediately after it files such application, provided, however, for sources that have previously utilized this provision during the term of the permit and, on two or more occasions have failed to file a complete application, may thereafter make the change only after the application is deemed complete. After the permittee makes the change and until the Tribe takes any of the actions specified in the following subsection, the permittee must comply with both the applicable requirements governing the change and the proposed permit terms and conditions. During this period, the permittee need not comply with the existing permit terms and conditions it seeks to modify. If the permittee fails to comply with its proposed permit terms and conditions during this period, however, the existing permit terms and conditions it seeks to modify may be enforced against it. The filing of a minor permit revision application does not authorize construction or modification of a source under the NSR preconstruction permit program. It is the permittee’s responsibility to determine if a preconstruction permit is required prior to commencing construction, modification, or reconstruction. [RAC 2-111(3)(e)] 1.8.5. The permit shield under RAC §2-110(10) does not extend to minor permit revisions. [RAC 2-110(10)(d)] 1.9. Significant Permit Revisions [RAC 2-111(4)] 1.9.1. The permittee must request the use of significant permit revision procedures as defined in RAC §1-103. 1.9.2. Significant permit revisions shall meet all requirements of the RAC for permit issuance and renewal, including those for applications, review by the Administrator and affected programs, and public participation. [RAC 2-111(4), 2-109, and 2-106(3)] 1.10. Permit Reopenings, Revocations and Reissuances, and Terminations [RAC 2112] 14 1.10.1. The permit may be reopened and revised for any of the reasons listed in the paragraphs below. Alternatively, the permit may be revoked and reissued for the reasons listed in the paragraphs below: 1.10.1.1. Additional requirements under the Clean Air Act become applicable to a major source with a remaining permit term of 3 or more years, provided that the Tribe shall revise such permits to incorporate such additional requirements no later than 18 months after promulgation of such requirements, and no such reopening is required if the effective date of the requirement is later than the permit expiration date unless the original permit or any of its terms or conditions have been extended past the permit expiration date pursuant to RAC §2-104(2)(b)(iii); 1.10.1.2. Additional requirements (including excess emissions requirements) become applicable to an affected source under the acid rain program. Upon approval by the Administrator, excess emissions offset plans shall be deemed to be incorporated into the permit; 1.10.1.3. The Tribe or the Administrator determines that the permit contains a material mistake or that inaccurate statements were made in establishing the terms or conditions of the permit; or 1.10.1.4. The Tribe or the Administrator determines that the permit must be revised or revoked and reissued to assure compliance with applicable requirements. 1.10.2. The permit may be terminated for any of the reasons listed below: 1.10.2.1. The permittee fails to meet the requirements of an approved compliance plan; 1.10.2.2. The permittee has been in significant or repetitious noncompliance with the operating permit terms or conditions; 1.10.2.3. The permittee has exhibited a history of willful disregard for environmental laws of any tribal or state authority, or of the United States; 1.10.2.4. The permittee has knowingly misrepresented a material fact in any application, record, report, plan, or other document filed or required to be maintained under the permit; 1.10.2.5. The permittee falsifies, tampers with, or renders inaccurate any monitoring device or method required to be maintained under the permit; 1.10.2.6. The permittee fails to pay fees required under RAC§§2-118 and 2-119; or 15 1.10.2.7. 1.11. The Administrator has found that cause exists to terminate the permit. Property Rights [RAC 2-110(3)(e)] This permit does not convey any property rights of any sort, or any exclusive privilege. 1.12. Inspection and Entry [RAC 2-110(9)(b)] Upon presentation of credentials and other documents as may be required by law, the permittee shall allow authorized representatives of the Tribe or other authorized representative to perform the following: 1.12.1. Enter upon the permittee’s premises where a source is located or emissionsrelated activity is conducted, or where records must be kept under the conditions of the permit; 1.12.2. Have access to and copy, at reasonable times, any records that must be kept under the conditions of the permit; 1.12.3. Inspect at reasonable times any facilities, equipment (including monitoring and air pollution control equipment), practices, or operations regulated or required under the permit; and 1.12.4. As authorized by the Clean Air Act, sample or monitor at reasonable times substances or parameters for the purpose of assuring compliance with the permit or applicable requirements. 1.13. [Reserved] 1.14. Permit Transfers [RAC 2-113] 1.14.1. This permit shall not be transferable, by operation of law or otherwise, from one location to another or from one source to another, except that a permit may be transferred from one location to another in the case of a portable source that has notified the Tribe in advance of the transfer, pursuant to the RAC. A permit for a source may be transferred from one person to another if the Tribe finds that the transferee is capable of operating the source in compliance with the permit. This transfer must be accomplished through an administrative permit revision in accordance with the Administrative Permit Revisions section of this permit. 1.15. Off-Permit Changes [RAC 2-116(2)] 16 1.15.1. The permittee is allowed to make, without a permit revision, certain changes that are not addressed or prohibited by this permit provided that the following requirements are met: 1.15.1.1. Each such change meets all applicable requirements and shall not violate any existing permit term or condition; 1.15.1.2. Such changes are not subject to any requirements under title IV of the Clean Air Act and are not modifications under title I of the Clean Air Act; 1.15.1.3. Such changes are not subject to permit revision procedures under RAC §2111; and 1.15.1.4. The permittee provides contemporaneous written notice to the Tribe and the Administrator of each such change, except for changes that qualify as insignificant activities. Such notice shall state when the change occurred and shall describe the change, any resulting emissions change, pollutants emitted, and any applicable requirement that would apply as a result of the change. [RAC 2-116(2)(a)] 1.15.2. The permit shield does not apply to changes made under this provision. [RAC 2-110(10)(d)] 1.15.3. The permittee shall keep a record describing changes made at the source that result in emissions of any regulated air pollutant subject to an applicable requirement, but not otherwise regulated under the permit, and the emissions resulting from those changes. [RAC 2-116(2)(b)] 1.15.4. A copy of each off-permit change notification shall be made available to the Tribe upon request. [RAC 2-110(6)] 1.16. Permit Expiration and Renewal [RAC §§2-104(3), 2-106(2)(b), 2-107(7)(a), 2-107(7)(b), 2-110(1)(a), and 2-106(3)] 1.16.1. This permit shall expire five years from the issuance date of this permit. [RAC 2-110(1)(a)] 1.16.2. Expiration of this permit terminates the permittee’s right to operate unless a timely and complete permit renewal application has been submitted at least 6 months but not more than 18 months prior to the date of expiration of this permit. [RAC 2-107(7)(b)] 17 1.16.3. If the permittee submits a timely and complete permit application for renewal, consistent with RAC §2-106 but the Tribe has failed to issue or disapprove a renewal permit before the end of the permit term, then the permit shall not expire and all its terms and conditions shall remain in effect until the renewal permit has been issued or disapproved. [RAC 2-104(2)(b)] 1.16.4. The ability to operate under this permit shall cease if (1) the Tribe takes final action to issue the permittee a renewal permit or deny the permittee a permit or (2) the permittee fails to submit by the deadline specified in writing by the Tribe any additional information identified as being needed to process the application. [RAC 2-104(3)] 1.16.5. Renewal of this permit is subject to the same procedures, including those for public participation and affected program and EPA review, as those that apply to initial permit issuance. [RAC 2-107(7)(a)] 1.16.6. The application for renewal shall include the current permit number, description of permit revisions and off permit changes that occurred during the permit term, any applicable requirements that were promulgated and not incorporated into the permit during the permit term, and other information required by the application form. [RAC 2-106(4)(e)(ix)] Facility-Wide Requirements Conditions in this section of the permit apply to all emissions units located at the facility, including any units not specifically listed in Table 1 or Table 2 of the Source Emission Points section of this permit. [RAC 2-110(1)(d)] 2.1. General Recordkeeping Requirements [RAC 2-110(6)] The permittee shall comply with the following generally applicable recordkeeping requirements: 2.1.1. If the permittee determines that his or her stationary source that emits (or has the potential to emit, without federally recognized controls) one or more hazardous air pollutants is not subject to a relevant standard or other requirement established under 40 CFR part 63, the permittee shall keep a record of the applicability determination, for a period of five years after the determination, or until the source changes its operations to become an affected source, whichever comes first. Each of these records shall be made available to the Tribe upon request. The record of the applicability determination shall include an analysis (or other 18 information) that demonstrates why the permittee believes the source is unaffected (e.g., because the source is an area source). [40 CFR 63.10(b)(3)] 2.1.2. Records shall be kept of off permit changes made, as required by the Off Permit Changes section of this permit. 2.2. General Reporting Requirements 2.2.1. The permittee shall submit to the Tribe all reports of any required monitoring under this permit semiannually, by April 1 and October 1 of each year. The report due on April 1 shall cover the July 1 - December 31 reporting period of the previous calendar year. The report due on October 1 shall cover the January 1 June 30 reporting period of the current calendar year. All instances of deviations from permit requirements shall be clearly identified in such reports. All required reports shall be certified by a responsible official consistent with the Submissions section of this permit. [RAC 2-110(7)(a)] 2.2.2. “Deviation” means any situation in which an emissions unit fails to meet a permit term or condition. A deviation is not always a violation. A deviation can be determined by observation or through review of data obtained from any testing, monitoring, or recordkeeping established in accordance with RAC 2-110(5) and (6). For a situation lasting more than 24 hours which constitutes a deviation, each 24 hour period is considered a separate deviation. Included in the meaning of deviation are any of the following: 2.2.2.1. A situation where emissions exceed an emission limitation or standard; 2.2.2.2. A situation where process or emissions control device parameter values indicate that an emission limitation or standard has not been met; or 2.2.2.3. A situation in which observations or data collected demonstrate noncompliance with an emission limitation or standard or any work practice or operating condition required by the permit. 2.2.2.4. A situation in which an exceedance or an excursion, as defined in 40 CFR Part 64 occurs. [RAC 1-103(21)] 2.2.3. The permittee shall promptly report to the Tribe deviations from permit requirements, (including emergencies), including the date, time, duration, and the probable cause of such deviations, the quantity and pollutant type of excess emissions resulting from the deviation, and any preventative, mitigation, or 19 corrective actions or measures taken. Prompt deviation reports shall be submitted to the following email address: airquality@southernute-nsn.gov 2.2.4. “Prompt” is defined as follows: 2.2.4.1. Where the underlying applicable requirement contains a definition of “prompt” or otherwise specifies a time frame for reporting deviations, that definition or time frame shall govern. 2.2.4.2. Where the underlying applicable requirement fails to address the time frame for reporting deviations, reports of deviations will be submitted based on the following schedule: 2.2.4.2.1. For emissions of a hazardous air pollutant or a toxic air pollutant (as identified in the applicable regulation) that continue for more than an hour in excess of permit requirements, the report must be made by email, telephone, verbal, or facsimile communication by the close of business the next working day, upon discovery of the occurrence, and in writing within 10 working days from the occurrence; 2.2.4.2.2. For emissions of any regulated air pollutant, excluding those listed in RAC §2-110(7)(b)(i), that continue for more than 2 hours in excess of permit requirements, the report must be made by email, telephone, verbal, or facsimile communication by the close of business the next working day, upon discovery of the occurrence, and in writing within 10 working days from the occurrence; 2.2.4.2.3. For all other deviations from permit requirements, the report shall be contained in the report submitted with the semi-annual monitoring report. [RAC 2-110(7)(b)] 2.3. Alternative Operating Scenarios [RAC 2-110(8)] 2.3.1. Replacement of an existing engine or turbine identified in this permit shall be allowed as an off-permit change pursuant to the Off Permit Changes provisions of this permit provided all of the following conditions are met: 2.3.1.1. The engine or turbine replacement is not subject to any requirements under Title IV of the Clean Air Act and is not a modification under Title I of the Clean Air Act; 2.3.1.2. The replacement engine or turbine is of the same make, model, horsepower rating, and configured to operate in the same manner as the engine or turbine being replaced. 20 2.3.1.3. The replacement engine or turbine meets all applicable requirements identified in this permit that apply to the existing engine or turbine being replaced. 2.3.1.4. All applicable requirements that apply to the replacement engine or turbine are already included in the permit. Replacement of an existing engine or turbine identified in this permit with a new, modified, or reconstructed engine must utilize a Minor Permit Revision as specified in RAC 2-111(3) or a Significant Permit Revision as specified in RAC 2111(4) to incorporate any new applicable requirements. The applicable requirements include, but may not be limited to: 2.3.1.4.1. Standards of Performance for Stationary Compression Ignition Internal Combustion at 40 CFR Part 60, Subpart IIII; 2.3.1.4.2. Standards of Performance for Stationary Spark Ignition Internal Combustion Engines at 40 CFR Part 60, Subpart JJJJ; 2.3.1.4.3. National Emission Standard for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines at 40 CFR Part 63, Subpart ZZZZ; 2.3.1.4.4. Standards of Performance for Stationary Gas Turbines at 40 CFR Part 60, Subpart GG; 2.3.1.4.5. Standards of Performance for Stationary Combustion Turbines at 40 CFR Part 60, Subpart KKKK; 2.3.1.4.6. National Emission Standard for Hazardous Air Pollutants for Stationary Combustion Turbines at 40 CFR Part 63, Subpart YYYY; 2.3.1.4.7. Requirements established in a permit or permits issued pursuant to the Federal Minor New Source Review Program in Indian Country at 40 CFR Part 49; 2.3.1.4.8. Requirements established in a permit or permits issued pursuant to the Prevention of Significant Deterioration of Air Quality Program at 40 CFR Part 52; or 2.3.1.4.9. Requirements established in any promulgated Federal Implementation Plan that may apply to engines located on the Southern Ute Indian Reservation. 21 2.3.2. The permittee shall provide contemporaneous written notice to the Tribe and the Administrator of any replacement of an existing engine or turbine identified in this permit. Such notice shall state when the replacement occurred and shall describe the replacement and any applicable requirement that would apply as a result of the replacement. 2.3.3. The permittee shall keep a record of the engine or turbine replacement. 2.3.4. The use of a backup thermal oxidizer with equivalent capacity and emission destruction efficiency and configured to operate in the same manner as the primary thermal oxidizer shall be an allowed alternative operating scenario under this permit provided that the following conditions are met: 2.3.4.1. Any emission limits, requirements, testing or other provisions that apply to the primary thermal oxidizer shall also apply to the backup thermal oxidizer except that an annual performance test shall only be conducted on the backup thermal oxidizer if the unit operates for more than 500 hours in any calendar year. 2.3.4.2. At no time shall the backup thermal oxidizer operate at the same time the primary thermal oxidizer is operating except periods of transition between the primary and backup thermal oxidizers. Transition events shall be documented, last no more than 30 minutes in duration, and will be reported as excess emission events. 2.4. Permit Shield [RAC 2-110(10)(c)] Nothing in this permit shall alter or affect the following: 2.4.1. The provisions of Section 303 of the Clean Air Act, 42 U.S.C. §7603 concerning emergency powers, including the respective authorities of the Administrator under those sections; 2.4.2. The liability of a permittee for any violation of applicable requirements prior to or at the time of permit issuance; 2.4.3. The applicable requirements of the acid rain program consistent with section 408(a) of the Act; or 2.4.4. The ability of the Administrator respectively to obtain information from a source pursuant to Section 114 of the Clean Air Act, 42 U.S.C. §7414. 2.5. Stratospheric Ozone and Climate Protection [40 CFR Part 82] 22 The permittee shall comply with the standards for recycling and emissions reduction pursuant to 40 CFR Part 82, Subpart F: 2.5.1. Persons opening appliances for maintenance, service, repair, or disposal must comply with the required practices pursuant to 40 CFR §82.156. 2.5.2. Equipment used during the maintenance, service, repair, or disposal of appliances must comply with the standards for recycling and recovery equipment pursuant to 40 CFR §82.158. 2.5.3. Persons performing maintenance, service, repair, or disposal of appliances must be certified by an approved technician certification program pursuant to 40 CFR §82.161. Section III – Site Specific Permit Terms New Source Performance Standards (NSPS) and 40 CFR Part 60 1.1. 40 CFR Part 60, Subpart OOOOb – Standards of Performance for Crude Oil and Natural Gas Facilities for Which Construction, Modification or Reconstruction Commenced After December 6, 2022 [40 CFR 60.5360b - 60.5439b] This facility is subject to the requirements of 40 CFR Part 60, Subpart OOOOb for the collection of fugitive emissions components at a compressor station. Notwithstanding conditions in this permit, the permittee shall comply with all applicable requirements of 40 CFR Part 60, subparts A and OOOOb. 1.1.1. Affected Sources The following emission units are considered affected sources under 40 CFR Part 60, Subpart OOOOb: The collection of fugitive emission components at a compressor station located at Trail Canyon Compressor Station. [40 CFR 60.5365b(i)(3)(i)] 1.1.2. General Requirements 1.1.2.1. At all times, including periods of startup, shutdown, and malfunction, owners and operators shall maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, 23 monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. The provisions for exemption from compliance during the periods of startup, shutdown and malfunctions provided for in 40 CFR 60.8(c) do not apply to this subpart. [40 CFR 60.5370b(b)] 1.1.3. Super-Emitter Events The provisions of this section will not apply between July 31, 2025, and January 22, 2027. The provisions of this section will apply after January 22, 2027. This section applies to super-emitter events. For purposes of this section, a super-emitter event is defined as any emissions event that is located at or near an oil and natural gas facility (e.g., individual well site, centralized production facility, natural gas processing plant, or compressor station) and that is detected using remote detection methods and has quantified emission rate of 100 kg/hr of methane or greater. §60.5371b(a) describes the qualifications one must meet to apply to be a third-party notifier of superemitter events. §60.5371b(b) describes the procedures for certifying thirdparty notifiers, as well as the procedures for petitioning the Agency for removal of a third-party notifier from the list of certified notifiers. §60.5371b(c) contains the required information that must be included in any notification submitted to the EPA from a certified third-party notifier and a timetable for notifications. The EPA shall review these notifications and if the EPA determines the notification is complete and does not contain information that the EPA finds to be erroneous or inaccurate to a reasonable degree of certainty, the EPA shall assign the notification a unique notification identification number, provide the notification to the owner or operator of the oil and natural gas facility identified in the notification, and post the notification, except for the owner/operator attribution, at www.epa.gov/superemitter. Upon receiving such notification, owners or operators must take the actions listed in §60.5371b(d) and (e). The EPA shall post the reports submitted under §60.5371b(e), §60.5371(b) and §60.5371a(b) of subparts OOOO and OOOOa of this part, and applicable State or Federal plan implementing §60.5388c(b) of subpart OOOOc of this part, including owner/operator attributions that have been confirmed by the reports; where the reporting deadlines have passed but no reports have been received, the EPA intends to post owner/operator attributions that the EPA reasonably believes to be accurate. The reports will be publicly available at www.epa.gov/superemitter. [40 CFR 60.5371b] 1.1.3.1. Identification of super-emitter events. Within 5 calendar days of receiving a notification from the EPA of a super-emitter event, the owner or operator of an oil and natural gas facility (e.g., a well site, centralized production facility, natural gas processing plant, or compressor station) 24 must initiate a super-emitter event investigation. The investigation must be conducted in accordance with this paragraph §60.5371b(d) and completed within 15 days of receiving the notification from the EPA. The owner or operator must maintain records of its super-emitter event investigations and report the findings from the investigation according to the requirements in §60.5371b(e). [40 CFR 60.5371b(d)] 1.1.3.1.1. If you do not own or operate an oil and natural gas facility within 50 meters from the latitude and longitude provided in the notification, report this result to the EPA under §60.5371b(e). Your super-emitter event investigation is deemed complete. [40 CFR 60.5371b(d)(1)] 1.1.3.1.2. If you own or operate an oil and natural gas facility within 50 meters from the latitude and longitude provided in the notification, you must investigate to determine the source of super-emitter event. The investigation may include but is not limited to the actions specified below in §60.5371b(d)(2)(i) through (v). [40 CFR 60.5371b(d)(2)] 1.1.3.1.2.1. Review any maintenance activities (e.g., liquids unloading) or process activities from the affected facilities subject to regulation under this subpart, starting from the date of detection of the super-emitter event as identified in the notification, until the date of investigation, to determine if the activities indicate any potential source(s) of the super-emitter event emissions. [40 CFR 60.5371b(d)(2)(i)] 1.1.3.1.2.2. Review all monitoring data from control devices (e.g., flares) from the affected facilities subject to regulation under this subpart from the initial date of detection of the super-emitter event as identified in the notification until the date of receiving the notification from the EPA. Identify any malfunctions of control devices or periods when the control devices were not in compliance with applicable requirements and that indicate a potential source of the super-emitter event emissions. [40 CFR 60.5371b(d)(2)(ii)] 1.1.3.1.2.3. If you conducted a fugitive emissions survey or periodic screening event in accordance with §60.5397b or 25 §60.5398b(b) between the initial date of detection of the super-emitter event as identified in the notification and the date the notification from the EPA was received, review the results of the survey to identify any potential source(s) of the super-emitter event emissions. [40 CFR 60.5371b(d)(2)(iii)] 1.1.3.1.2.4. If you conduct continuous monitoring with advanced methane detection technology in accordance with §60.5398b(c), review the monitoring data collected on or after the initial date of detection of the super-emitter event as identified in the notification, until the date of receiving the notification from the EPA. [40 CFR 60.5371b(d)(2)(iv)] 1.1.3.1.2.5. Screen the entire oil and natural gas facility with OGI, Method 21 of appendix A-7 to this part, or an alternative test method(s) approved per §60.5398b(d), to determine if a super-emitter event is present. [40 CFR 60.5371b(d)(2)(v)] 1.1.3.1.3. If the source of the super-emitter event was found to be from fugitive emission components at a well site, centralized production facility, or compressor station subject to this subpart, you must comply with the repair requirements under §60.5397b and the associated recordkeeping and reporting requirements under §60.5420b(b)(9) and (c)(14). [40 CFR 60.5371b(d)(3)] 1.1.3.2. Super-emitter event report. You must submit the results of the superemitter event investigation conducted under §60.5371b(d) to the EPA in accordance with §60.5371b(e)(1). If the super-emitter event (i.e., emission at 100 kg/hr of methane or more) is ongoing at the time of the initial report, submit the additional information in accordance with §60.5371b(e)(2). You must attest to the information included in the report as specified in §60.5371b(e)(3). [40 CFR 60.5371b(e)] 1.1.3.2.1. Within 15 days of receiving a notification from the EPA under §60.5371b(c), you must submit a report of the super-emitter event investigation conducted under §60.5371b(d) through the Super-Emitter Program Portal. You must include the applicable information in §60.5371b(e)(1)(i) through (viii) in the report. If you have identified a demonstrable error in the notification, the report may include a statement of the demonstrable error. 26 [40 CFR 60.5371b(e)(1)] 1.1.3.2.1.1. Notification Report ID of the super-emitter event notification. [40 CFR 60.5371b(e)(1)(i)] 1.1.3.2.1.2. Identification of whether you are the owner or operator of an oil and natural gas facility within 50 meters from the latitude and longitude provided in the EPA notification. If you do not own or operate an oil and natural gas facility within 50 meters from the latitude and longitude provided in the EPA notification, you are not required to report the information in §60.5371b(e)(1)(iii) through (viii). [40 CFR 60.5371b(e)(1)(ii)] 1.1.3.2.1.3. General identification information for the facility, including, facility name, the physical address, applicable ID Number (e.g., EPA ID Number, API Well ID Number), the owner or operator or responsible official (where applicable) and their email address. [40 CFR 60.5371b(e)(1)(iii)] 1.1.3.2.1.4. Identification of whether there is an affected facility or associated equipment subject to regulation under this subpart at this oil and natural gas facility. [40 CFR 60.5371b(e)(1)(iv)] 1.1.3.2.1.5. Indication of whether you were able to identify the source of the super-emitter event. If you indicate you were unable to identify the source of the super-emitter event, you must certify that all applicable investigations specified in §60.5371b(d)(2)(i) through (v) have been conducted for all affected facilities and associated equipment subject to this subpart that are at this oil and natural gas facility, and you have determined that the affected facilities and associated equipment are not the source of the super-emitter event. If you indicate that you were not able to identify the source of the super-emitter event, you are not required to report the information in §60.5371b(e)(1)(vi) through (viii). [40 CFR 60.5371b(e)(1)(v)] 1.1.3.2.1.6. The source(s) of the super-emitter event. [40 CFR 60.5371b(e)(1)(vi)] 27 1.1.3.2.1.7. Identification of whether the source of the super-emitter event is equipment subject to regulation under this subpart. If the source of the super-emitter event is equipment subject to regulation under this subpart, identify the applicable regulation(s) under this subpart. [40 CFR 60.5371b(e)(1)(vii)] 1.1.3.2.1.8. Indication of whether the super-emitter event is ongoing at the time of the initial report submittal (i.e., emissions at 100 kg/hr of methane or more). [40 CFR 60.5371b(e)(1)(viii)] 1.1.3.2.1.8.1. If the super-emitter event is not ongoing at the time of the initial report submittal, provide the actual (or if unknown) estimated date and time the super-emitter event ended. [40 CFR 60.5371b(e)(1)(viii)(A)] 1.1.3.2.1.8.2. If the super-emitter event is ongoing at the time of the initial report submittal, provide a short narrative of your plan to end the super-emitter event, including the targeted end date for the efforts to be completed and the super-emitter event ended. [40 CFR 60.5371b(e)(1)(viii)(B)] 1.1.3.2.2. If the super-emitter event is ongoing at the time of the initial report submittal, within 5 business days of the date the superemitter event ends, you must update your initial report through the Super-Emitter Program Portal to provide the end date and time of the super-emitter event. [40 CFR 60.5371b(e)(2)] 1.1.3.2.3. You must sign the following attestation when submitting data into the Super-Emitter Program Portal: “I certify that the information provided in this report regarding the specified super-emitter event was prepared under my direction or supervision. I further certify that the investigations were conducted, and this report was prepared pursuant to the requirements of §60.5371b(d) and (e). Based on my professional knowledge and experience, and inquiry of personnel involved in the assessment, the certification submitted herein is true, accurate, and complete. I am aware that knowingly false statements may be punishable by fine or imprisonment.” 28 [40 CFR 60.5371b(e)(3)] 1.1.4. Standards for Fugitive Emissions Components Affected Facilities 1.1.4.1. General requirements. You must monitor all fugitive emissions components affected facilities in accordance with §60.5397b(b) through (g). You must repair all sources of fugitive emissions in accordance with §60.5397b(h). You must demonstrate initial compliance in accordance with §60.5397b(i). You must keep records in accordance with §60.5397b(j) and report in accordance with §60.5397b(k). [40 CFR 60.5397b(a)] 1.1.4.2. Develop fugitive emissions monitoring plan. You must develop a fugitive emissions monitoring plan that covers all fugitive emissions components affected facilities within each company-defined area in accordance with §60.5397b(c) and (d). [40 CFR 60.5397b(b)] 1.1.4.3. Elements of fugitive emissions monitoring plan. Your fugitive emissions monitoring plan must include the elements specified in §60.5397b(c)(1) through (8), at a minimum. [40 CFR 60.5397b(c)] 1.1.4.3.1. Frequency for conducting surveys. Surveys must be conducted at least as frequently as required by §60.5397b(f) and (g). [40 CFR 60.5397b(c)(1)] 1.1.4.3.2. Technique for determining fugitive emissions (i.e., AVO or other detection methods, Method 21 of appendix A-7 to this part, and/or OGI and meeting the requirements of §60.5397b(c)(7)(i) through (vii)). [40 CFR 60.5397b(c)(2)] 1.1.4.3.3. Manufacturer and model number of fugitive emissions detection equipment to be used, if applicable. [40 CFR 60.5397b(c)(3)] 1.1.4.3.4. Procedures and timeframes for identifying and repairing fugitive emissions components from which fugitive emissions are detected, including timeframes for fugitive emission components that are unsafe to repair. Your repair schedule must meet the requirements of §60.5397b(h) at a minimum. [40 CFR 60.5397b(c)(4)] 29 1.1.4.3.5. Procedures and timeframes for verifying fugitive emission component repairs. [40 CFR 60.5397b(c)(5)] 1.1.4.3.6. Records that will be kept and the length of time records will be kept. [40 CFR 60.5397b(c)(6)] 1.1.4.3.7. If you are using OGI, your plan must also include the elements specified in §60.5397b(c)(7)(i) through (vii). [40 CFR 60.5397b(c)(7)] 1.1.4.3.7.1. Verification that your OGI equipment meets the specifications of §60.5397b(c)(7)(i)(A) and (B). This verification is an initial verification, and may either be performed by the facility, by the manufacturer, or by a third party. For the purposes of complying with the fugitive emissions monitoring program with OGI, fugitive emissions are defined as any visible emissions observed using OGI. [40 CFR 60.5397b(c)(7)(i)] 1.1.4.3.7.1.1. Your OGI equipment must be capable of imaging gases in the spectral range for the compound of highest concentration n the potential fugitive emissions. [40 CFR 60.5397b(c)(7)(i)(A)] 1.1.4.3.7.1.2. Your OGI equipment must be capable of imaging a gas that is half methane, half propane at a concentration of 10,000 ppm at a flow rate of ≤60 g/hr from a quarter inch diameter orifice. [40 CFR 60.5397b(c)(7)(i)(B)] 1.1.4.3.7.2. Procedure for a daily verification check. [40 CFR 60.5397b(c)(7)(ii)] 1.1.4.3.7.3. Procedure for determining the operator’s maximum viewing distance from the equipment and how the operator will ensure that this distance is maintained. [40 CFR 60.5397b(c)(7)(iii)] 1.1.4.3.7.4. Procedure for determining maximum wind speed during which monitoring can be performed and how the operator 30 will ensure monitoring occurs only at wind speeds below this threshold. [40 CFR 60.5397b(c)(7)(iv)] 1.1.4.3.7.5. Procedures for conducting surveys, including the items specified in §60.5397b(c)(7)(v)(A) through (C). [40 CFR 60.5397b(c)(7)(v)] 1.1.4.3.7.5.1. How the operator will ensure an adequate thermal background is present in order to view potential fugitive emissions. [40 CFR 60.5397b(c)(7)(v)(A)] 1.1.4.3.7.5.2. How the operator will deal with adverse monitoring conditions, such as wind. [40 CFR 60.5397b(c)(7)(v)(B)] 1.1.4.3.7.5.3. How the operator will deal with interferences (e.g., steam). [40 CFR 60.5397b(c)(7)(v)(C)] 1.1.4.3.7.6. Training and experience needed prior to performing surveys. [40 CFR 60.5397b(c)(7)(vi)] 1.1.4.3.7.7. Procedures for calibration and maintenance. At a minimum, procedures must comply with those recommended by the manufacturer. [40 CFR 60.5397b(c)(7)(vii)] 1.1.4.3.8. If you are using Method 21 of appendix A-7 to this part, your plan must also include the elements specified in §60.5397b(c)(8)(i) through (iv). For the purposes of complying with the fugitive emissions monitoring program using Method 21 of appendix A-7 to this part a fugitive emission is defined as an instrument reading of 500 ppmv or greater. [40 CFR 60.5397b(c)(8)] 1.1.4.3.8.1. Verification that your monitoring equipment meets the requirements specified in Section 6.0 of Method 21 of appendix A-7 to this part. For purposes of instrument capability, the fugitive emissions definition shall be 500 ppmv or greater methane using a FID-based instrument. If you wish to use an analyzer other than an FID-based instrument, you must develop a site-specific fugitive 31 emission definition that would be equivalent to 500 ppmv methane using a FID-based instrument (e.g., 10.6 eV PID with a specified isobutylene concentration as the fugitive emission definition would provide equivalent response to your compound of interest). [40 CFR 60.5397b(c)(8)(i)] 1.1.4.3.8.2. Procedures for conducting surveys. At a minimum, the procedures shall ensure that the surveys comply with the relevant sections of Method 21 of appendix A-7 to this part, including Section 8.3.1. [40 CFR 60.5397b(c)(8)(ii)] 1.1.4.3.8.3. Procedures for calibration. The instrument must be calibrated before use each day of its use by the procedures specified in Method 21 of appendix A-7 to this part. At a minimum, you must also conduct precision tests at the interval specified in Method 21 of appendix A-7 to this part, Section 8.1.2, and a calibration drift assessment at the end of each monitoring day. The calibration drift assessment must be conducted as specified in §60.5397b(c)(8)(iii)(A). Corrective action for drift assessments is specified in §60.5397b(c)(8)(iii)(B) and (C). [40 CFR 60.5397b(c)(8)(iii)] 1.1.4.3.8.3.1. Check the instrument using the same calibration gas that was used to calibrate the instrument before use. Follow the procedures specified in Method 21 of appendix A-7 to this part, Section 10.1, except do not adjust the meter readout to correspond to the calibration gas value. If multiple scales are used, record the instrument reading for each scale used. Divide the arithmetic difference of the initial and post-test calibration response by the corresponding calibration gas value for each scale and multiply by 100 to express the calibration drift as a percentage. [40 CFR 60.5397b(c)(8)(iii)(A)] 1.1.4.3.8.3.2. If a calibration drift assessment shows a negative drift of more than 10 percent, then all equipment with instrument readings between the fugitive emission definition multiplied by (100 32 minus the percent of negative drift) divided by 100 and the fugitive emission definition that was monitored since the last calibration must be re-monitored. [40 CFR 60.5397b(c)(8)(iii)(B)] 1.1.4.3.8.3.3. If any calibration drift assessment shows a positive drift of more than 10 percent from the initial calibration value, then, at the owner/operator's discretion, all equipment with instrument readings above the fugitive emission definition and below the fugitive emission definition multiplied by (100 plus the percent of positive drift) divided by 100 monitored since the last calibration may be re-monitored. [40 CFR 60.5397b(c)(8)(iii)(C)] 1.1.4.3.8.4. Procedures for monitoring yard piping (other than buried yard piping). At a minimum, place the probe inlet at the surface of the yard piping and run the probe down the length of the piping. Connection points on the piping must be monitored following the procedures specified in Method 21 of appendix A-7 to this part. [40 CFR 60.5397b(c)(8)(iv)] 1.1.4.4. Additional elements of fugitive emissions monitoring plan. Each fugitive emissions monitoring plan must include the elements specified in §60.5397b(d)(1) and (2), at a minimum, as applicable. [40 CFR 60.5397b(d)] 1.1.4.4.1. If you are using OGI, your plan must include procedures to ensure that all fugitive emissions components, except buried yard piping and associated components (e.g., connectors), are monitored during each survey. Example procedures include, but are not limited to, a sitemap with an observation path, a written narrative of where the fugitive emissions components are located and how they will be monitored, or an inventory of fugitive emissions components. [40 CFR 60.5397b(d)(1)] 1.1.4.4.2. If you are using Method 21 of appendix A-7 to this part, your plan must include a list of fugitive emissions components to be monitored and method for determining the location of fugitive emissions components to be monitored in the field (e.g., tagging, identification on a process and instrumentation 33 diagram, etc.). Your fugitive emissions monitoring plan must include the written plan developed for all of the fugitive emissions components designated as difficult-to-monitor in accordance with §60.5397b(g)(2), and the written plan for fugitive emissions components designated as unsafe-to-monitor in accordance with §60.5397b(g)(3). [40 CFR 60.5397b(d)(2)] 1.1.4.5. Monitoring of fugitive emissions components. Each fugitive emissions component, except buried yard piping and associated components (e.g., connectors), shall be observed or monitored for fugitive emissions during each monitoring survey. [40 CFR 60.5397b(e)] 1.1.4.6. Initial monitoring survey. You must conduct initial monitoring surveys according to the requirement specified in §60.5397b(f)(3). [40 CFR 60.5397b(f)] 1.1.4.6.1. For a modified or reconstructed fugitive emissions components affected facility, the initial monitoring survey must be conducted within 90 days of the startup of production for each fugitive emissions components affected facility after the modification or reconstruction. [40 CFR 60.5397b(f)(3)] 1.1.4.7. Monitoring frequency. A monitoring survey of each fugitive emissions components affected facility must be performed as specified in §60.5397 (g)(1), with the exceptions noted in §60.5397b(g)(2) and (3). [40 CFR 60.5397b(g)] 1.1.4.7.1. A monitoring survey of the fugitive emissions components affected facilities must be conducted using the methods and at the frequencies specified in in §60.5397b(g)(1)(v). [40 CFR 60.5397b(g)(1)] 1.1.4.7.1.1. A monitoring survey of the fugitive emissions components affected facility located at a compressor station must be conducted at the frequencies in §60.5397b(g)(1)(v)(A) and (B). [40 CFR 60.5397b(g)(1)(v)] 1.1.4.7.1.1.1. A monitoring survey must be conducted at least monthly using AVO, or any other detection method, after the initial survey. Any indications of fugitive emissions using these methods are 34 considered fugitive emissions that must be repaired in accordance with §60.5397b(h). [40 CFR 60.5397b(g)(1)(v)(A)] 1.1.4.7.1.1.2. A monitoring survey must be conducted at least quarterly using OGI or Method 21 of appendix A-7 to this part after the initial survey. Consecutive quarterly monitoring surveys must be conducted at least 60 calendar days apart. [40 CFR 60.5397b(g)(1)(v)(B)] 1.1.4.7.2. If you are using Method 21 of appendix A-7 to this part, fugitive emissions components that cannot be monitored without elevating the monitoring personnel more than 2 meters above the surface may be designated as difficult-to-monitor. Fugitive emissions components that are designated difficult-tomonitor must meet the specifications of §60.5397b(g)(2)(i) through (iv). [40 CFR 60.5397b(g)(2)] 1.1.4.7.2.1. A written plan must be developed for all the fugitive emissions components designated difficult-to-monitor. This written plan must be incorporated into the fugitive emissions monitoring plan required by §60.5397b(b), (c), and (d). [40 CFR 60.5397b(g)(2)(i)] 1.1.4.7.2.2. The plan must include the identification and location of each fugitive emissions component designated as difficult-to-monitor. [40 CFR 60.5397b(g)(2)(ii)] 1.1.4.7.2.3. The plan must include an explanation of why each fugitive emissions component designated as difficult-tomonitor is difficult-to-monitor. [40 CFR 60.5397b(g)(2)(iii)] 1.1.4.7.2.4. The plan must include a schedule for monitoring the difficult-to-monitor fugitive emissions components at least once per calendar year. [40 CFR 60.5397b(g)(2)(iv)] 1.1.4.7.3. If you are using Method 21 of appendix A-7 to this part, fugitive emissions components that cannot be monitored because monitoring personnel would be exposed to immediate 35 danger while conducting a monitoring survey may be designated as unsafe-to-monitor. Fugitive emissions components that are designated unsafe-to-monitor must meet the specifications of §60.5397b(g)(3)(i) through (iv). [40 CFR 60.5397b(g)(3)] 1.1.4.7.3.1. A written plan must be developed for all the fugitive emissions components designated unsafe-to-monitor. This written plan must be incorporated into the fugitive emissions monitoring plan required by §60.5397b(b), (c), and (d). [40 CFR 60.5397b(g)(3)(i)] 1.1.4.7.3.2. The plan must include the identification and location of each fugitive emissions component designated as unsafeto-monitor. [40 CFR 60.5397b(g)(3)(ii)] 1.1.4.7.3.3. The plan must include an explanation of why each fugitive emissions component designated as unsafe-tomonitor is unsafe-to-monitor. [40 CFR 60.5397b(g)(3)(iii)] 1.1.4.7.3.4. The plan must include a schedule for monitoring the fugitive emissions components designated as unsafe-tomonitor. [40 CFR 60.5397b(g)(3)(iv)] 1.1.4.8. Repairs. Each identified source of fugitive emissions shall be repaired in accordance with §60.5397b(h)(1) and (2). [40 CFR 60.5397b(h)] 1.1.4.8.1. A first attempt at repair shall be made in accordance with §60.5397b(h)(1)(i) and (ii). [40 CFR 60.5397b(h)(1)] 1.1.4.8.1.1. A first attempt at repair shall be made no later than 15 calendar days after detection of fugitive emissions that were identified using AVO. [40 CFR 60.5397b(h)(1)(i)] 1.1.4.8.1.2. If you are using OGI or Method 21 of appendix A-7 to this part, a first attempt at repair shall be made no later than 30 calendar days after detection of the fugitive emissions. 36 [40 CFR 60.5397b(h)(1)(ii)] 1.1.4.8.2. Repair shall be completed as soon as practicable, but no later than 15 calendar days after the first attempt at repair as required in §60.5397b(h)(1)(i), and 30 calendar days after the first attempt at repair as required in §60.5397b(h)(1)(ii). [40 CFR 60.5397b(h)(2)] 1.1.4.8.3. Delay of repair will be allowed if the conditions in §60.5397b(h)(3)(i) or (ii) are met. [40 CFR 60.5397b(h)(3)] 1.1.4.8.3.1. If the repair is technically infeasible, would require a vent blowdown, a compressor station shutdown, a well shutdown or well shut-in, or would be unsafe to repair during operation of the unit, the repair must be completed during the next scheduled compressor station shutdown for maintenance, scheduled well shutdown, scheduled well shut-in, after a scheduled vent blowdown, or within 2 years of detecting the fugitive emissions, whichever is earliest. A vent blowdown is the opening of one or more blowdown valves to depressurize major production and processing equipment, other than a storage vessel. [40 CFR 60.5397b(h)(3)(i)] 1.1.4.8.3.2. If the repair requires replacement of a fugitive emissions component or a part thereof, but the replacement cannot be acquired and installed within the repair timelines specified in §60.5397b(h)(1) and (2) due to either of the conditions specified in §60.5397b(h)(3)(ii)(A) or (B), the repair must be completed in accordance with §60.5397b(h)(3)(ii)(C) and documented in accordance with §60.5420b(c)(14)(v)(I). [40 CFR 60.5397b(h)(3)(ii)] 1.1.4.8.3.2.1. Valve assembly supplies had been sufficiently stocked but are depleted at the time of the required repair. [40 CFR 60.5397b(h)(3)(ii)(A)] 1.1.4.8.3.2.2. A replacement fugitive emissions component or a part thereof requires custom fabrication. [40 CFR 60.5397b(h)(3)(ii)(B)] 37 1.1.4.8.3.2.3. The required replacement must be ordered no later than 10 calendar days after the first attempt at repair. The repair must be completed as soon as practicable, but no later than 30 calendar days after receipt of the replacement component, unless the repair requires a compressor station or well shutdown. If the repair requires a compressor station or well shutdown, the repair must be completed in accordance with the timeframe specified in §60.5397b(h)(3)(i). [40 CFR 60.5397b(h)(3)(ii)(C)] 1.1.4.8.4. Each identified source of fugitive emissions must be resurveyed to complete repair according to the requirements of §60.5397b(h)(4)(i) through (v), to ensure that there are no fugitive emissions. [40 CFR 60.5397b(h)(4)] 1.1.4.8.4.1. The operator may resurvey the fugitive emissions components to verify repair using either Method 21 of appendix A-7 to this part or OGI, except as specified in §60.5397b(h)(4)(v). [40 CFR 60.5397b(h)(4)(i)] 1.1.4.8.4.2. For each repair that cannot be made during the monitoring survey when the fugitive emissions are initially found, a digital photograph must be taken of that component, or the component must be tagged during the monitoring survey when the fugitive emissions were initially found for identification purposes and subsequent repair. The digital photograph must include the date that the photograph was taken and must clearly identify the component by location within the site (e.g., the latitude and longitude of the component or by other descriptive landmarks visible in the picture). [40 CFR 60.5397b(h)(4)(ii)] 1.1.4.8.4.3. Operators that use Method 21 of appendix A-7 to this part to resurvey the repaired fugitive emissions components are subject to the resurvey provisions specified in §60.5397b(h)(4)(iii)(A) and (B). [40 CFR 60.5397b(h)(4)(iii)] 1.1.4.8.4.3.1. A fugitive emissions component is repaired when the Method 21 instrument indicates a 38 concentration of less than 500 ppmv above background or when no soap bubbles are observed when the alternative screening procedures specified in section 8.3.3 of Method 21 of appendix A-7 to this part are used. [40 CFR 60.5397b(h)(4)(iii)(A)] 1.1.4.8.4.3.2. Operators must use the Method 21 monitoring requirements specified in §60.5397b(c)(8)(ii) or the alternative screening procedures specified in section 8.3.3 of Method 21 of appendix A-7 to this part. [40 CFR 60.5397b(h)(4)(iii)(B)] 1.1.4.8.4.4. Operators that use OGI to resurvey the repaired fugitive emissions components are subject to the resurvey provisions specified in §60.5397b(h)(4)(iv)(A) and (B). [40 CFR 60.5397b(h)(4)(iv)] 1.1.4.8.4.4.1. A fugitive emissions component is repaired when the OGI instrument shows no indication of visible emissions. [40 CFR 60.5397b(h)(4)(iv)(A)] 1.1.4.8.4.4.2. Operators must use the OGI monitoring requirements specified in §60.5397b(c)(7). [40 CFR 60.5397b(h)(4)(iv)(B)] 1.1.4.8.4.5. For fugitive emissions identified using AVO detection methods, the operator may resurvey using those same methods, Method 21 of appendix A-7 to this part, or OGI. For operators that use AVO detection methods, a fugitive emissions component is repaired when there are no indications of fugitive emissions using these methods. [40 CFR 60.5397b(h)(4)(v)] 1.1.5. Initial Compliance with the Standards for the Collection of Fugitive Emissions Components at a Compressor Station. You must determine initial compliance with the standards for each affected facility using the requirements of §60.5410b(k). Except as otherwise provided in this section, the initial compliance period begins on the date specified in §60.5370b and ends no later than 1 year after that date. The initial compliance period may be less than 1 full year. 39 1.1.5.1. Fugitive emission components affected facility. To achieve initial compliance with the GHG and VOC standards for fugitive emissions components affected facilities as required by §60.5397b, you must comply with §60.5410b(k)(1) through (5). [40 CFR 60.5410b(k)] 1.1.5.1.1. You must develop a fugitive emissions monitoring plan as required in §60.5397b(b), (c), and (d). [40 CFR 60.5410b(k)(1)] 1.1.5.1.2. You must conduct an initial monitoring survey as required in §60.5397b(e) and (f). [40 CFR 60.5410b(k)(2)] 1.1.5.1.3. You must repair each identified source of fugitive emissions for each affected facility as required in §60.5397b(h). [40 CFR 60.5410b(k)(3)] 1.1.5.1.4. You must repair each identified source of fugitive emissions for each affected facility as required in §60.5397b(h). [40 CFR 60.5410b(k)(4)] 1.1.5.1.5. You must maintain the records specified in §60.5420b(c)(14). [40 CFR 60.5410b(k)(5)] 1.1.6. Continuous Compliance with the Standards for the Collection of Fugitive Emissions Components at a Compressor Station. 1.1.6.1. Continuous compliance. For each fugitive emissions components affected facility, you must demonstrate continuous compliance with the requirements of §60.5397b(a) according to §60.5415b(l)(1) through (4). [40 CFR 60.5415b(l)] 1.1.6.1.1. Monitoring. You must conduct periodic monitoring surveys as required in §60.5397b(e) and (g). [40 CFR 60.5415b(l)(1)] 1.1.6.1.2. Repairs. You must repair each identified source of fugitive emissions as required in §60.5397b(h). [40 CFR 60.5415b(l)(2)] 1.1.6.1.3. Reports. You must submit annual reports for fugitive emissions components affected facilities as required in §60.5420b(b)(1) and (9). [40 CFR 60.5415b(l)(3)] 40 1.1.6.1.4. Records. You must maintain records as specified in §60.5420b(c)(14). [40 CFR 60.5415b(l)(4)] 1.1.7. Notification, Reporting, and Recordkeeping Requirements. 1.1.7.1. Notifications. You must submit notifications according to §60.5420b(a)(1) if you own or operate one or more of the affected facilities specified in §60.5365b that was constructed, modified, or reconstructed during the reporting period. [40 CFR 60.5420b(a)] 1.1.7.1.1. If you own or operate a collection of fugitive emissions components at a compressor station affected facility, you are not required to submit the notifications required in §§60.7(a)(1), (3), and (4) and 60.15(d). [40 CFR 60.5420b(a)(1)] 1.1.7.2. Reporting requirements. You must submit annual reports containing the information specified in §60.5420b(b)(1), (9), and (14) following the procedure specified in §60.5420b(b)(15). The initial annual report is due no later than 90 days after the end of the initial compliance period as determined according to §60.5410b. Subsequent annual reports are due no later than the same date each year as the initial annual report. If you own or operate more than one affected facility, you may submit one report for multiple affected facilities provided the report contains all of the information required as specified in §60.5420b(b)(1), (9), and (14). Annual reports may coincide with title V reports as long as all the required elements of the annual report are included. You may arrange with the Administrator a common schedule on which reports required by this part may be submitted as long as the schedule does not extend the reporting period. [40 CFR 60.5420b(b)] 1.1.7.2.1. The general information specified in §60.5420b(b)(1)(i) through (iv) is required for all reports. [40 CFR 60.5420b(b)(1)] 1.1.7.2.1.1. The company name, facility site name associated with the affected facility, and address of the affected facility. If an address is not available for the site, include a description of the site location and provide the latitude and longitude coordinates of the site in decimal degrees to an accuracy 41 and precision of five (5) decimals of a degree using the North American Datum of 1983. [40 CFR 60.5420b(b)(1)(i)] 1.1.7.2.1.2. An identification of each affected facility being included in the annual report. [40 CFR 60.5420b(b)(1)(ii)] 1.1.7.2.1.3. Beginning and ending dates of the reporting period. [40 CFR 60.5420b(b)(1)(iii)] 1.1.7.2.1.4. A certification by a certifying official of truth, accuracy, and completeness. This certification shall state that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete. If your report is submitted via CEDRI, the certifier's electronic signature during the submission process replaces the requirement in this paragraph. [40 CFR 60.5420b(b)(1)(iv)] 1.1.7.2.2. For the fugitive emissions components affected facility, report the information specified in §60.5420b(b)(9)(i) and (ii), as applicable. [40 CFR 60.5420b(b)(9)] 1.1.7.2.2.1.1. Designation of the type of site (i.e., well site, centralized production facility, or compressor station) at which the fugitive emissions components affected facility is located. [40 CFR 60.5420b(b)(9)(i)(A)] 1.1.7.2.2.1.2. For the fugitive emissions components affected facility at a compressor station that became an affected facility during the reporting period, you must include the date of startup or the date of modification. [40 CFR 60.5420b(b)(9)(i)(B)] 1.1.7.2.2.2. For each fugitive emissions monitoring survey performed during the annual reporting period, the information specified in §60.5420b(b)(9)(ii)(A) through (G). [40 CFR 60.5420b(b)(9)(ii)] 1.1.7.2.2.2.1. Date of the survey. 42 [40 CFR 60.5420b(b)(9)(ii)(A)] 1.1.7.2.2.2.2. Monitoring instrument or, if the survey was conducted by AVO methods, notation that AVO was used. [40 CFR 60.5420b(b)(9)(ii)(B)] 1.1.7.2.2.2.3. Any deviations from the monitoring plan elements under §60.5397b(c)(1), (2), and (7), (c)(8)(i), or (d) or a statement that there were no deviations from these elements of the monitoring plan. [40 CFR 60.5420b(b)(9)(ii)(C)] 1.1.7.2.2.2.4. Number and type of components for which fugitive emissions were detected. [40 CFR 60.5420b(b)(9)(ii)(D)] 1.1.7.2.2.2.5. Number and type of fugitive emissions components that were not repaired as required in §60.5397b(h). [40 CFR 60.5420b(b)(9)(ii)(E)] 1.1.7.2.2.2.6. Number and type of fugitive emission components (including designation as difficultto-monitor or unsafe-to-monitor, if applicable) on delay of repair and explanation for each delay of repair. [40 CFR 60.5420b(b)(9)(ii)(F)] 1.1.7.2.2.2.7. Date of planned shutdown(s) that occurred during the reporting period if there are any components that have been placed on delay of repair. [40 CFR 60.5420b(b)(9)(ii)(G)] 1.1.7.2.3. If you had a super-emitter event during the reporting period, the start date of the super-emitter event, the duration of the super-emitter event in hours, and the affected facility associated with the super-emitter event, if applicable. [40 CFR 60.5420b(b)(14)] 1.1.7.2.4. You must submit your annual report using the appropriate electronic report template on the Compliance and Emissions Data Reporting Interface (CEDRI) website for this subpart and 43 following the procedure specified in §60.5420b(d). If the reporting form specific to this subpart is not available on the CEDRI website at the time that the report is due, you must submit the report to the Administrator at the appropriate address listed in §60.4. Once the form has been available on the CEDRI website for at least 90 calendar days, you must begin submitting all subsequent reports via CEDRI. The date reporting forms become available will be listed on the CEDRI website. Unless the Administrator or delegated state agency or other authority has approved a different schedule for submission of reports, the report must be submitted by the deadline specified in this subpart, regardless of the method in which the report is submitted. [40 CFR 60.5420b(b)(15)] 1.1.7.3. Recordkeeping requirements. You must maintain the records identified as specified in §60.7(f) and in §60.5420b(c)(14). All records required by this subpart must be maintained either onsite or at the nearest local field office for at least 5 years. Any records required to be maintained by this subpart that are submitted electronically via the EPA's CEDRI may be maintained in electronic format. This ability to maintain electronic copies does not affect the requirement for facilities to make records, data, and reports available upon request to a delegated air agency or the EPA as part of an on-site compliance evaluation. [40 CFR 60.5420b(c)] 1.1.7.3.1. For the fugitive emissions components affected facility, maintain the records identified in §60.5420b(c)(14)(i), (iv), and (v). [40 CFR 60.5420b(c)(14)] 1.1.7.3.1.1. The date of startup or the date of modification for the fugitive emissions components affected facility at a compressor station. [40 CFR 60.5420b(c)(14)(i)] 1.1.7.3.1.2. The fugitive emissions monitoring plan as required in §60.5397b(b), (c), and (d). [40 CFR 60.5420b(c)(14)(iv)] 1.1.7.3.1.3. The records of each monitoring survey as specified in §60.5420b(c)(14)(v)(A) through (I). [40 CFR 60.5420b(c)(14)(v)] 1.1.7.3.1.3.1. Date of the survey. 44 [40 CFR 60.5420b(c)(14)(v)(A)] 1.1.7.3.1.3.2. Beginning and end time of the survey. [40 CFR 60.5420b(c)(14)(v)(B)] 1.1.7.3.1.3.3. Name of operator(s), training, and experience of the operator(s) performing the survey. [40 CFR 60.5420b(c)(14)(v)(C)] 1.1.7.3.1.3.4. Monitoring instrument or method used. [40 CFR 60.5420b(c)(14)(v)(D)] 1.1.7.3.1.3.5. Fugitive emissions component identification when Method 21 of appendix A-7 to this part is used to perform the monitoring survey. [40 CFR 60.5420b(c)(14)(v)(E)] 1.1.7.3.1.3.6. Ambient temperature, sky conditions, and maximum wind speed at the time of the survey. For compressor stations, operating mode of each compressor (i.e., operating, standby pressurized, and not operating-depressurized modes) at the station at the time of the survey. [40 CFR 60.5420b(c)(14)(v)(F)] 1.1.7.3.1.3.7. Any deviations from the monitoring plan or a statement that there were no deviations from the monitoring plan. [40 CFR 60.5420b(c)(14)(v)(G)] 1.1.7.3.1.3.8. Records of calibrations for the instrument used during the monitoring survey. [40 CFR 60.5420b(c)(14)(v)(H)] 1.1.7.3.1.3.9. Documentation of each fugitive emission detected during the monitoring survey, including the information specified in §60.5420b(c)(14)(v)(I)(1) through (9). [40 CFR 60.5420b(c)(14)(v)(I)] 1.1.7.3.1.3.9.1. Location of each fugitive emission identified. [40 CFR 60.5420b(c)(14)(v)(I)(1)] 45 1.1.7.3.1.3.9.2. Type of fugitive emissions component, including designation as difficult-tomonitor or unsafe-to-monitor, if applicable. [40 CFR 60.5420b(c)(14)(v)(I)(2)] 1.1.7.3.1.3.9.3. If Method 21 of appendix A-7 to this part is used for detection, record the component ID and instrument reading. [40 CFR 60.5420b(c)(14)(v)(I)(3)] 1.1.7.3.1.3.9.4. For each repair that cannot be made during the monitoring survey when the fugitive emissions are initially found, a digital photograph or video must be taken of that component or the component must be tagged for identification purposes. The digital photograph must include the date that the photograph was taken and must clearly identify the component by location within the site (e.g., the latitude and longitude of the component or by other descriptive landmarks visible in the picture). The digital photograph or identification (e.g., tag) may be removed after the repair is completed, including verification of repair with the resurvey. [40 CFR 60.5420b(c)(14)(v)(I)(4)] 1.1.7.3.1.3.9.5. The date of first attempt at repair of the fugitive emissions component(s). [40 CFR 60.5420b(c)(14)(v)(I)(5)] 1.1.7.3.1.3.9.6. The date of successful repair of the fugitive emissions component, including the resurvey to verify repair and instrument used for the resurvey. [40 CFR 60.5420b(c)(14)(v)(I)(6)] 1.1.7.3.1.3.9.7. Identification of each fugitive emission component placed on delay of repair and explanation for each delay of repair. [40 CFR 60.5420b(c)(14)(v)(I)(7)] 46 1.1.7.3.1.3.9.8. For each fugitive emission component placed on delay of repair for reason of replacement component unavailability, the operator must document: the date the component was added to the delay of repair list, the date the replacement fugitive component or part thereof was ordered, the anticipated component delivery date (including any estimated shipment or delivery date provided by the vendor), and the actual arrival date of the component. [40 CFR 60.5420b(c)(14)(v)(I)(8)] 1.1.7.3.1.3.9.9. Date of planned shutdowns that occur while there are any components that have been placed on delay of repair. [40 CFR 60.5420b(c)(14)(v)(I)(9)] 1.1.7.4. Electronic reporting. If you are required to submit notifications or reports following the procedure specified in this paragraph, you must submit notifications or reports to the EPA via CEDRI, which can be accessed through the EPA's Central Data Exchange (CDX) (https://cdx.epa.gov/). The EPA will make all the information submitted through CEDRI available to the public without further notice to you. Do not use CEDRI to submit information you claim as CBI. Although we do not expect persons to assert a claim of CBI, if you wish to assert a CBI claim for some of the information in the report or notification, you must submit a complete file in the format specified in this subpart, including information claimed to be CBI, to the EPA following the procedures in §60.5420b(d). Clearly mark the part or all of the information that you claim to be CBI. Information not marked as CBI may be authorized for public release without prior notice. Information marked as CBI will not be disclosed except in accordance with procedures set forth in 40 CFR part 2. All CBI claims must be asserted at the time of submission. Anything submitted using CEDRI cannot later be claimed CBI. Furthermore, under CAA section 114(c), emissions data is not entitled to confidential treatment, and the EPA is required to make emissions data available to the public. Thus, emissions data will not be protected as CBI and will be made publicly available. You must submit the same file submitted to the CBI office with the CBI omitted to the EPA via the EPA's CDX as described earlier in this paragraph. [40 CFR 60.5420b(d)] 47 1.1.7.5. Claims of EPA system outage. If you are required to electronically submit a notification or report through CEDRI in the EPA's CDX, you may assert a claim of EPA system outage for failure to timely comply with that requirement. To assert a claim of EPA system outage, you must meet the requirements outlined in paragraphs §60.5420b(e)(1) through (7). [40 CFR 60.5420b(e)] 1.1.7.5.1. You must have been or will be precluded from accessing CEDRI and submitting a required report within the time prescribed due to an outage of either the EPA’s CEDRI or CDX systems. [40 CFR 60.5420b(e)(1)] 1.1.7.5.2. The outage must have occurred within the period of time beginning five business days prior to the date that the submission is due. [40 CFR 60.5420b(e)(2)] 1.1.7.5.3. The outage may be planned or unplanned. [40 CFR 60.5420b(e)(3)] 1.1.7.5.4. You must submit notification to the Administrator in writing as soon as possible following the date you first knew, or through due diligence should have known, that the event may cause or has caused a delay in reporting. [40 CFR 60.5420b(e)(4)] 1.1.7.5.5. You must provide to the Administrator a written description identifying: [40 CFR 60.5420b(e)(5)] 1.1.7.5.5.1. The date(s) and time(s) when CDX or CEDRI was accessed and the system was unavailable; [40 CFR 60.5420b(e)(5)(i)] 1.1.7.5.5.2. A rationale for attributing the delay in reporting beyond the regulatory deadline to EPA system outage; [40 CFR 60.5420b(e)(5)(ii)] 1.1.7.5.5.3. A description of measures taken or to be taken to minimize the delay in reporting; and [40 CFR 60.5420b(e)(5)(iii)] 48 1.1.7.5.5.4. The date by which you propose to report, or if you have already met the reporting requirement at the time of the notification, the date you reported. [40 CFR 60.5420b(e)(5)(iv)] 1.1.7.5.6. The decision to accept the claim of EPA system outage and allow an extension to the reporting deadline is solely within the discretion of the Administrator. [40 CFR 60.5420b(e)(6)] 1.1.7.5.7. In any circumstance, the report must be submitted electronically as soon as possible after the outage is resolved. [40 CFR 60.5420b(e)(7)] 1.1.7.6. Claims of force majeure. If you are required to electronically submit a report or notification through CEDRI in the EPA's CDX, you may assert a claim of force majeure for failure to timely comply with that requirement. To assert a claim of force majeure, you must meet the requirements outlined in paragraphs §60.5420b(f)(1) through (5). [40 CFR 60.5420b(f)] 1.1.7.6.1. You may submit a claim if a force majeure event is about to occur, occurs, or has occurred or there are lingering effects from such an event within the period of time beginning five business days prior to the date the submission is due. For the purposes of this section, a force majeure event is defined as an event that will be or has been caused by circumstances beyond the control of the affected facility, its contractors, or any entity controlled by the affected facility that prevents you from complying with the requirement to submit a report electronically within the time period prescribed. Examples of such events are acts of nature (e.g., hurricanes, earthquakes, or floods), acts of war or terrorism, or equipment failure or safety hazard beyond the control of the affected facility (e.g., large scale power outage). [40 CFR 60.5420b(f)(1)] 1.1.7.6.2. You must submit notification to the Administrator in writing as soon as possible following the date you first knew, or through due diligence should have known, that the event may cause or has caused a delay in reporting. [40 CFR 60.5420b(f)(2)] 1.1.7.6.3. You must provide to the Administrator: [40 CFR 60.5420b(f)(3)] 49 1.1.7.6.3.1. A written description of the force majeure event; [40 CFR 60.5420b(f)(3)(i)] 1.1.7.6.3.2. A rationale for attributing the delay in reporting beyond the regulatory deadline to the force majeure event; [40 CFR 60.5420b(f)(3)(ii)] 1.1.7.6.3.3. A description of measures taken or to be taken to minimize the delay in reporting; and [40 CFR 60.5420b(f)(3)(iii)] 1.1.7.6.3.4. The date by which you propose to report, or if you have already met the reporting requirement at the time of the notification, the date you reported. [40 CFR 60.5420b(f)(3)(iv)] 1.1.7.6.3.5. The decision to accept the claim of force majeure and allow an extension to the reporting deadline is solely within the discretion of the Administrator. [40 CFR 60.5420b(f)(4)] 1.1.7.6.3.6. In any circumstance, the reporting must occur as soon as possible after the force majeure event occurs. [40 CFR 60.5420b(f)(5)] 1.1.7.7. General Provisions Table 5 to this subpart shows which parts of the General Provisions in §§60.1 through 60.19 apply to you. [40 CFR 60.5425b] Table 5 to Subpart OOOOb of Part 60 - Applicability of General Provisions to Subpart OOOOb General Applies to provisions Subject of citation Explanation subpart? citation General applicability §60.1 of the General Yes Provisions §60.2 Definitions Yes Additional terms defined in §60.5430b. Units and §60.3 Yes abbreviations §60.4 Address Yes Determination of §60.5 construction or Yes modification §60.6 Review of plans Yes 50 §60.7 §60.8 §60.9 §60.10 §60.11 §60.12 §60.13 Notification and record keeping Performance tests Availability of information State authority Compliance with standards and maintenance requirements Circumvention Monitoring requirements Yes Except that §60.7 only applies as specified in §§60.5417b(c) and 60.5420b(a). Yes Except that the format and submittal of performance test reports is described in §60.5420b(b) and (d). Performance testing is required for control devices used on storage vessels, centrifugal compressors, and pneumatic pumps, except that performance testing is not required for a control device used solely on pneumatic pump(s). Yes Yes No Yes §60.14 Modification Yes §60.15 Reconstruction Yes §60.16 Priority list Incorporations by reference General control device and work practice requirements General notification and reporting requirement Yes §60.17 §60.18 §60.19 Requirements are specified in subpart OOOOb. To the extent any provision in §60.14 conflicts with specific provisions in subpart OOOOb, it is superseded by subpart OOOOb provisions. Except that §60.15(d) does not apply to wells (i.e., well completions, well liquids unloading, associated gas wells), process controllers, pumps, centrifugal compressors, reciprocating compressors, storage vessels, or fugitive emissions components affected facilities. Yes Yes Yes National Emission Standards for Hazardous Air Pollutants (NESHAP) and 40 CFR Part 63 2.1. 40 CFR Part 63, Subpart HH – National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities [40 CFR 63.760 – 63.779, RAC 4-103] [If applying the use of ProMax® (ProMax), Red Cedar should continue to adhere to the Subpart HH language as written in their current permits with the exception that ProMax Version 5.0 or higher may be used in place of GRI-GLYCalc for the specific provisions identified in the EPA approval memo. The use of ProMax is an alternative EPA approved method (ALT-147). Should Red Cedar elect to use ProMax as an alternative method, Red Cedar may not use another method until receiving AQD approval.] 51 This facility is subject to the requirements of 40 CFR Part 63, Subpart HH for large dehydrator(s) located at an area source of hazardous air pollutants (HAPs). Notwithstanding conditions in this permit, the permittee shall comply with all applicable requirements of 40 CFR Part 63, subparts A and HH. 2.1.1. General Standards 2.1.1.1. Table 2 of this subpart specifies the provisions of subpart A (General Provisions) of this part that apply and those that do not apply to owners and operators of affected sources subject to this subpart. [40 CFR 63.764(a)] Table 2 to Subpart HH of Part 63 – Applicability of 40 CFR Part 63 General Provisions to Subpart HH General provisions Applicable to reference subpart HH §63.1(a)(1) Yes. §63.1(a)(2) Yes. §63.1(a)(3) Yes. §63.1(a)(4) Yes. §63.1(a)(5) No §63.1(a)(6) Yes. §63.1(a)(7) through (a)(9) No §63.1(a)(10) Yes. §63.1(a)(11) Yes. §63.1(a)(12) Yes. §63.1(b)(1) No §63.1(b)(2) No §63.1(b)(3) Yes. §63.1(c)(1) No §63.1(c)(2) Yes §63.1(c)(3) and (c)(4) §63.1(c)(5) §63.1(d) §63.1(e) No Yes. No Yes. §63.2 Yes §63.3(a) through (c) §63.4(a)(1) through (a)(2) §63.4(a)(3) through (a)(5) §63.4(b) §63.4(c) §63.5(a)(1) §63.5(a)(2) §63.5(b)(1) Yes. Yes. No Yes. Yes. Yes. Yes. Yes. Explanation Section reserved. Section reserved. Subpart HH specifies applicability. Section reserved. Subpart HH specifies applicability. Subpart HH exempts area sources from the requirement to obtain a Title V permit unless otherwise required by law as specified in §63.760(h). Section reserved. Section reserved. Except definition of major source is unique for this source category and there are additional definitions in subpart HH. Section reserved. 52 §63.5(b)(2) §63.5(b)(3) §63.5(b)(4) §63.5(b)(5) §63.5(b)(6) §63.5(c) §63.5(d)(1) §63.5(d)(2) §63.5(d)(3) §63.5(d)(4) §63.5(e) §63.5(f)(1) §63.5(f)(2) §63.6(a) §63.6(b)(1) §63.6(b)(2) §63.6(b)(3) §63.6(b)(4) §63.6(b)(5) §63.6(b)(6) §63.6(b)(7) §63.6(c)(1) §63.6(c)(2) §63.6(c)(3) through (c)(4) §63.6(c)(5) §63.6(d) §63.6(e)(1)(i) §63.6(e)(1)(ii) §63.6(e)(1)(iii) §63.6(e)(2) §63.6(e)(3) §63.6(f)(1) §63.6(f)(2) §63.6(f)(3) §63.6(g) §63.6(h)(1) §63.6(h)(2) through (h)(9) §63.6(i)(1) through (i)(14) §63.6(i)(15) §63.6(i)(16) §63.6(j) §63.7(a)(1) No Yes. Yes. No Yes. No Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. No Yes. Yes. Yes. No Yes. No No No. Yes. No No. No. Yes. Yes. Yes. No. Yes. Yes. No Yes. Yes. Yes. §63.7(a)(2) Yes §63.7(a)(3) §63.7(a)(4) Yes. Yes. Section reserved. Section Reserved. Section reserved. Section reserved. Section reserved. Section reserved. See §63.764(j) for general duty requirement. Section reserved. Section reserved. But the performance test results must be submitted within 180 days after the compliance date. 53 §63.7(c) §63.7(d) §63.7(e)(1) §63.7(e)(2) §63.7(e)(3) §63.7(e)(4) §63.7(f) §63.7(g) §63.7(h) §63.8(a)(1) §63.8(a)(2) §63.8(a)(3) §63.8(a)(4) §63.8(b)(1) §63.8(b)(2) §63.8(b)(3) §63.8(c)(1) §63.8(c)(1)(i) §63.8(c)(1)(ii) §63.8(c)(1)(iii) §63.8(c)(2) §63.8(c)(3) §63.8(c)(4) §63.8(c)(4)(i) §63.8(c)(4)(ii) §63.8(c)(5) through (c)(8) §63.8(d)(1) §63.8(d)(2) Yes. Yes. No. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. No Yes. Yes. Yes. Yes. No. No. Yes. No. Yes. Yes. Yes. No Yes. Yes. Yes. Yes. §63.8(d)(3) Yes §63.8(e) Yes §63.8(f)(1) through (f)(5) §63.8(f)(6) Yes. Yes. §63.8(g) No §63.9(a) §63.9(b)(1) Yes. Yes. §63.9(b)(2) Yes §63.9(b)(3) §63.9(b)(4) §63.9(b)(5) §63.9(c) §63.9(d) No Yes. Yes. Yes. Yes. Section reserved. Subpart HH does not require continuous opacity monitors. Except for last sentence, which refers to an SSM plan. SSM plans are not required. Subpart HH does not specifically require continuous emissions monitor performance evaluation, however, the Administrator can request that one be conducted. Subpart HH specifies continuous monitoring system data reduction requirements. Existing sources are given 1 year (rather than 120 days) to submit this notification. Major and area sources that meet §63.764(e) do not have to submit initial notifications. Section reserved. 54 §63.9(e) §63.9(f) §63.9(g) Yes. Yes. Yes. §63.9(h)(1) through (h)(3) Yes §63.9(h)(4) §63.9(h)(5) through (h)(6) §63.9(i) §63.9(j) §63.10(a) No Yes. Yes. Yes. Yes. §63.10(b)(1) Yes §63.10(b)(2) §63.10(b)(2)(i) Yes. No. §63.10(b)(2)(ii) No §63.10(b)(2)(iii) §63.10(b)(2)(iv) through (b)(2)(v) §63.10(b)(2)(vi) through (b)(2)(xiv) Yes. §63.10(b)(3) Yes §63.10(c)(1) §63.10(c)(2) through (c)(4) §63.10(c)(5) through (c)(8) §63.10(c)(9) §63.10(c)(10) through (11) §63.10(c)(12) through (14) §63.10(c)(15) §63.10(d)(1) Yes. No Yes. No No Yes. No. Yes. Section reserved. See §63.774(g) for recordkeeping of malfunctions. §63.10(d)(2) Yes Area sources located outside UA plus offset and UC boundaries do not have to submit performance test reports. §63.10(d)(3) §63.10(d)(4) §63.10(d)(5) Yes. Yes. No §63.10(e)(1) Yes §63.10(e)(2) Yes §63.10(e)(3)(i) Yes §63.10(e)(3)(i)(A) §63.10(e)(3)(i)(B) §63.10(e)(3)(i)(C) §63.10(e)(3)(i)(D) Yes. Yes. No. Yes Area sources located outside UA plus offset and UC boundaries are not required to submit notifications of compliance status. Section reserved. §63.774(b)(1) requires sources to maintain the most recent 12 months of data on-site and allows offsite storage for the remaining 4 years of data. See §63.774(g) for recordkeeping of (1) occurrence and duration and (2) actions taken during malfunctions. No. Yes. §63.774(b)(1) requires sources to maintain the most recent 12 months of data on-site and allows offsite storage for the remaining 4 years of data. Sections reserved. See §63.775(b)(6) or (c)(6) for reporting of malfunctions. Area sources located outside UA plus offset and UC boundaries are not required to submit reports. Area sources located outside UA plus offset and UC boundaries are not required to submit reports. Subpart HH requires major sources to submit Periodic Reports semiannually. Area sources are required to submit Periodic Reports annually. Area sources located outside UA plus offset and UC boundaries are not required to submit reports. Section reserved. 55 §63.10(e)(3)(ii) through (viii) §63.10(e)(4) §63.10(f) §63.11(a) and (b) §63.11(c), (d), and (e) §63.12(a) through (c) §63.13(a) through (c) §63.14(a) through (q) §63.15(a) and (b) §63.16 2.1.1.2. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. Yes. All reports required under this subpart shall be sent to the Tribe at the address below. Reports may be submitted on electronic media. [40 CFR 63.764(b)] by email at: airquality@southernute-nsn.gov or by United States Postal Service: Part 70 Program Environmental Programs Department Air Quality Division P.O. Box 737 MS #84 Ignacio, Colorado 81137 2.1.1.3. or by Common Carrier: Part 70 Program Environmental Programs Department Air Quality Division 398 Ouray Drive Ignacio, CO 81137 The owner or operator of an affected source located at an existing or new area source of HAP emissions shall comply with the applicable standards specified below. [40 CFR 63.764(d)] 2.1.1.3.1. Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with §63.764(d)(2)(i) through (iii). [40 CFR 63.764(d)(2)] 2.1.1.3.1.1. Determine the optimum glycol circulation rate using the following equation. 𝑳𝑶𝑷𝑻 = 𝟏. 𝟏𝟓 ∗ 𝟑. 𝟎 56 𝒈𝒂𝒍 𝑻𝑬𝑮 𝑭 ∗ (𝑰 − 𝑶) ∗ 𝒍𝒃 𝑯𝟐 𝑶 𝟐𝟒 𝒉𝒓/𝒅𝒂𝒚 Where: LOPT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMSCF/D). I = Inlet water content (lb/MMSCF). O = Outlet water content (lb/MMSCF). 3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/lb H2O). 1.15 = Adjustment factor included for a margin of safety. [40 CFR 63.764(d)(2)(i)] 2.1.1.3.1.2. Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i). If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate determined in accordance with paragraph §63.764(d)(2)(i), the owner or operator must calculate an alternate circulation rate using GRIGLYCalcTM, Version 3.0 or higher, or ProMax. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate and submit this documentation with the initial notification in accordance with §63.775(c)(7). [40 CFR 63.764(d)(2)(ii)] 2.1.1.3.1.3. Maintain a record of the determination specified in §63.764(d)(2)(ii) in accordance with the requirements in §63.774(f) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with §63.764(d)(2)(i) or (ii) and submit the information specified under §63.775(c)(7)(ii) through (v). [40 CFR 63.764(d)(2)(iii)] 2.1.1.4. At all times the owner or operator must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air 57 pollution control practices for minimizing emissions. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. [40 CFR 63.764(j)] 2.1.2. Test Methods, Compliance Procedures, and Compliance Demonstrations 2.1.2.1. Determination of glycol dehydration unit flowrate, benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions. [40 CFR 63.772(b)] 2.1.2.1.1. The determination of actual flowrate of natural gas to a glycol dehydration unit shall be made using §63.772(b)(1)(ii). [40 CFR 63.772(b)(1)] 2.1.2.1.1.1. The owner or operator shall document, to the Administrator’s satisfaction, the actual annual average natural gas flowrate to the glycol dehydration unit. [40 CFR 63.772(b)(1)(ii)] 2.1.2.1.2. The determination of actual average benzene or BTEX emissions from a glycol dehydration unit shall be made using the procedures of §63.772(b)(2)(i). Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. [40 CFR 63.772(b)(2)] 2.1.2.1.2.1. The owner or operator shall determine actual average benzene or BTEX emissions using an approved model (GRI-GLYCalcTM, Version 3.0 or higher, or ProMax). If GRI-GLYCalcTM is used, follow the procedures presented in the associated GRI-GLYCalcTM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled “Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions” (GRI-95/0368.1). [40 CFR 63.772(b)(2)(i)] 58 2.1.3. Recordkeeping Requirements 2.1.3.1. Except as specified in §63.774(f), each owner or operator of a facility subject to this subpart shall maintain the records specified in §63.774(b)(1) and (2). [40 CFR 63.774(b)] 2.1.3.1.1. The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. [40 CFR 63.774(b)(1)] 2.1.3.1.1.1. All applicable records shall be maintained in such a manner that they can be readily accessed. [40 CFR 63.774(b)(1)(i)] 2.1.3.1.1.2. The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request. [40 CFR 63.774(b)(1)(ii)] 2.1.3.1.1.3. The remaining 4 years of records may be retained offsite. [40 CFR 63.774(b)(1)(iii)] 2.1.3.1.1.4. Records may be maintained in hard copy or computerreadable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche. [40 CFR 63.774(b)(1)(iv)] 2.1.3.1.2. Records specified in §63.10(b)(2). [40 CFR 63.774(b)(2)] 2.1.3.2. The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. [40 CFR 63.774(f)] 2.1.3.3. The owner or operator of an affected source subject to this subpart shall maintain records of the occurrence and duration of each malfunction of 59 operation (i.e., process equipment) or the air pollution control equipment and monitoring equipment. The owner or operator shall maintain records of actions taken during periods of malfunction to minimize emissions in accordance with §63.764(j), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation. [40 CFR 63.774(g)] 2.1.4. Reporting Requirements 2.1.4.1. The owner or operator of an area source subject to this subpart shall submit the information listed in §63.775(c)(1). If the source is not located within any UA plus offset and UC boundaries, the owner or operator shall also submit the information listed within §63.775(c)(7). [40 CFR 63.775(c)] 2.1.4.1.1. In addition to submitting your initial notification to the addressees specified under §63.9(a), you must also submit a copy of the initial notification to the EPA's Office of Air Quality Planning and Standards. Send your notification via email to Oil and Gas Sector@epa.gov or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Fuels and Incineration Group (E143-01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711. [40 CFR 63.775(c)(1)] 2.1.4.1.2. The information listed in §63.775(c)(1)(i) through (v) shall be submitted with the initial notification. [40 CFR 63.775(c)(7)] 2.1.4.1.2.1. Documentation of the source's location relative to the nearest UA plus offset and UC boundaries. This information shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the name of the nearest urban cluster with 10,000 people or more and nearest urbanized area. [40 CFR 63.775(c)(7)(i)] 2.1.4.1.2.2. Calculation of the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i). [40 CFR 63.775(c)(7)(ii)] 60 2.1.4.1.2.3. If applicable, documentation of the alternate glycol circulation rate calculated using GRI-GLYCalcTM, Version 3.0 or higher, or ProMax, and documentation stating why the TEG dehydration unit must operate using the alternate glycol circulation rate. [40 CFR 63.775(c)(7)(iii)] 2.1.4.1.2.4. The name of the manufacturer and the model number of the glycol circulation pump(s) in operation. [40 CFR 63.775(c)(7)(iv)] 2.1.4.1.2.5. Statement by a responsible official, with that official's name, title, and signature, certifying that the facility will always operate the glycol dehydration unit using the optimum circulation rate determined in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. [40 CFR 63.775(c)(7)(v)] 2.1.4.2. Each owner or operator of a source subject to this subpart shall submit a Notification of Compliance Status Report as required under §63.9(h) within 180 days after the compliance date specified in §63.760(f). In addition to the information required under §63.9(h), the Notification of Compliance Status Report shall include the information specified in §63.775(d)(7), (9), and (10). This information may be submitted in an operating permit application, in an amendment to an operating permit application, in a separate submittal, or in any combination of the three. If all of the information required under this paragraph has been submitted at any time prior to 180 days after the applicable compliance dates specified in §63.760(f), a separate Notification of Compliance Status Report is not required. If an owner or operator submits the information specified in §63.775(d)(7), (9), and (10) at different times, and/or different submittals, subsequent submittals may refer to previous submittals instead of duplicating and resubmitting the previously submitted information. [40 CFR 63.775(d)] 2.1.4.2.1. After a title V permit has been issued to the owner or operator of an affected source, the owner or operator of such source shall comply with [Text truncated at 120,000 characters. The full text is on the page linked above.] --- Source: Frix Law Library, https://www.frixlaw.com/law-library/documents/tribal%3Asouthern_ute%3A0de6875756e1d6b3. Public record. Not legal advice.