2024-13206. Standards of Performance for New, Reconstructed, and Modified Sources and Emissions Guidelines for Existing Sources: Oil and Natural Gas Sector Climate Review: Correction
Table 1—Industrial Source Categories Affected by the NSPS and EG Actions
Category NAICS code 1 Examples of regulated entities Industry 211120 Crude Petroleum Extraction. 211130 Natural Gas Extraction. 221210 Natural Gas Distribution. 486110 Pipeline Distribution of Crude Oil. 486210 Pipeline Transportation of Natural Gas. Federal Government Not affected. State and Local Government Not affected. Tribal Government 921150 American Indian and Alaska Native Tribal Governments. 1 North American Industry Classification System (NAICS). This table is not intended to be exhaustive, but rather to provide a guide for readers regarding entities likely to be affected by the technical corrections and clarifications. Other types of entities not listed in the table could also be affected by this action. To determine whether your entity is affected by any of the corrections to the final rule in this action, you should carefully examine the applicability criteria found in NSPS OOOOa, NSPS OOOOb and EG OOOOc. If you have questions regarding the applicability of this action to a particular entity, consult the person listed in the FOR FURTHER INFORMATION CONTACT section.
C. Statutory Authority
Statutory authority to issue the amendments finalized in this action is provided by the same CAA provisions that provided authority to issue the regulations being amended: CAA section 111(b)(1)(B) (requirement to review, and if appropriate, revise, standards of performance for new sources at least every 8 years) and CAA section 111(d) (requirement to establish standards of performance for existing sources for certain pollutants to which a Federal NSPS would apply if such existing source were a new source). Statutory authority for the rulemaking procedures followed in this action is provided by Administrative Procedure Act (APA) section 553(b)(B), 5 U.S.C. 553(b)(B) (good cause exception to notice and comment rulemaking).
D. Judicial Review and Administrative Review
Under CAA section 307(b)(1), judicial review of this final action is available only by filing a petition for review in the United States Court of Appeals for the District of Columbia Circuit by September 30, 2024. Under CAA section 307(b)(2), the requirements established by this final action may not be challenged separately in any civil or criminal proceedings brought by the EPA to enforce the requirements.
II. Regulatory Revisions
A. Background and Summary
On November 15, 2021, the EPA published a proposed rule (November 2021 Proposal) to mitigate climate-destabilizing pollution and protect human health by reducing greenhouse gas (GHG) and volatile organic compound (VOC) emissions from the oil and natural gas industry,[1] specifically the Crude Oil and Natural Gas source category.[2 3] In the November 2021 Proposal, the EPA proposed new standards of performance under section 111(b) of the CAA for GHGs (in the form of methane limitations) and VOC emissions from new, modified, and reconstructed sources in this source category, as well as revisions to standards of performance already codified at 40 CFR part 60, subparts OOOO and OOOOa. The EPA also proposed EG under section 111(d) of the CAA for GHGs emissions (in the form of methane limitations) from existing sources (designated facilities).[4] The EPA also proposed several related actions stemming from the joint resolution of Congress, adopted on June 30, 2021, under the Congressional Review Act (CRA), disapproving the EPA's final rule titled, “Oil and Natural Gas Sector: Emission Standards for New, Reconstructed, and Modified Sources Review,” September 14, 2020 (2020 Policy Rule). Lastly, in the November 2021 Proposal the EPA proposed a protocol under the general provisions for optical gas imaging (OGI).
On December 6, 2022, the EPA published a supplemental proposed rule (“December 2022 Supplemental Proposal”) that was composed of 2 main additions.[5] First, the EPA updated, strengthened, and expanded on the NSPS OOOOb standards proposed in November 2021 under CAA section 111(b) for GHGs (in the form of methane limitations) and VOC emissions from new, modified, and reconstructed facilities. Second, the EPA updated, strengthened, and expanded the presumptive standards proposed for EG OOOOc in the November 2021 Proposal as part of the CAA section 111(d) EG for GHGs emissions (in the form of methane limitations) from designated facilities. For purposes of EG OOOOc, the EPA also proposed the implementation requirements for state plans developed to limit GHGs pollution (in the form of methane limitations) from designated facilities in the Crude Oil and Natural Gas source category under CAA section 111(d).
On March 8, 2024, at 89 FR 16820, the EPA published the final rule with multiple actions to reduce air emissions from the Crude Oil and Natural Gas source category. First, the EPA finalized an NSPS OOOOb regulating GHG (in the form of a limitation on emissions of methane) and VOCs emissions for the Crude Oil and Natural Gas source category pursuant to CAA section 111(b)(1)(B). Second, the EPA finalized the presumptive standards in EG OOOOc to limit GHGs. Third, the EPA finalized several related actions (including final amendments to NSPS OOOOa) stemming from the joint resolution of Congress, adopted on June 30, 2021, under the CRA, disapproving the 2020 Policy Rule. The final rule became effective sixty days after publication, which was May 7, 2024.
As discussed in the summary of this preamble, after the publication of the final rule, the EPA discovered, through its own internal reassessment of the regulatory text, as well as through communications with stakeholders and the Office of Federal Register, erroneous cross-references and typographical errors within the regulatory text. Through those same processes, the EPA also identified erroneous language in the regulatory text (or in some cases, erroneous omissions) requiring minor wording changes in order to conform with the final rule preamble and other parts of the regulatory text. The technical corrections and clarifications identified herein are being made to address such unintended errors in the recently finalized regulations. The final rule is extensive, covering many individual emissions sources at thousands of facilities in the oil and natural gas industry across the country. The EPA acknowledges the importance of finalizing these corrections to the regulatory text as soon as possible so that the regulated community can rely on regulatory text that is accurate and complete and avoid confusion about how to comply with the final rule. This action addresses the technical errors in the final rule identified to date by stakeholders, the Office of the Federal Register, and the EPA. This action does not attempt to address all issues identified by stakeholders following the rules' promulgation. The EPA continues to review other issues that have been brought to the Agency's attention but are not addressed in this action. To the extent the EPA determines that additional action is appropriate to address other post-promulgation issues, we will initiate a separate rulemaking action. As explained in further detail in sections II.B-D, and in section IV, the EPA is taking this action as an interim final rule without prior proposal and public comment because the EPA finds that this action satisfies the good cause exemption from the notice and comment rulemaking requirement of the APA, 5 U.S.C. 553(b)(B).
B. Technical Corrections for NSPS OOOOa
Following signature of the final rule, we identified typographical errors included in the amendments to NSPS OOOOa. This action corrects those typographical errors, which are summarized below. In 40 CFR 60.5430a, the EPA identified a typographical error in the definition of “ Equipment. ” The final rule inadvertently excluded the word “and” between “equipment leaks of GHG (in the form of methane)” and “VOC.” This omission is clear from a plain reading of the text. This technical error of omission is corrected in this action. In addition, the EPA identified typographical errors in mathematical symbols used in tables in both NSPS OOOOa and NSPS OOOOb. These mathematical symbol errors are corrected by this action in both NSPS OOOOa and NSPS OOOOb. In the amendments to NSPS OOOOa of the final rule, these errors were identified in Table 1 to Subpart OOOOa of Part 60—Required Minimum Initial sulfur dioxide (SO2) Emission Reduction Efficiency (Zi) and Table 2 to Subpart OOOOa of Part 60—Required Minimum SO2 Emission Reduction Efficiency (Zc). In NSPS OOOOb, these errors were identified in Table 3 to Subpart OOOOb of Part 60—Required Minimum Initial SO2 Emission Reduction Efficiency (Zi) and Table 4 to Subpart OOOOb of Part 60—Required Minimum SO2 Emission Reduction Efficiency (Zc). The inadvertent typographical errors therein are the mathematical symbols “≤” and “≥” which were mistakenly included in the final rule as “<”and “>”. These technical typographical errors are corrected in this action. Note that the corrections to the mathematical symbols in these tables parallel what is included in similar tables in NSPS OOOO, which are correct. The substance of the final rule remains unchanged by correcting these typographical errors. Thus, the EPA finds good cause to make these corrections to the final rule without prior notice or comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B). A red line and strike-out version of the corrected regulatory language for NSPS OOOOa amendment is available in Docket ID No. EPA-HQ-OAR-2021-0317.
C. Technical Corrections for NSPS OOOOb
1. Cross-Reference, Paragraph Designation, and Typographical Technical Corrections
Following signature of the final rule, stakeholders and the Office of the Federal Register brought to the Agency's attention, and the EPA itself identified, inadvertent errors in the regulatory text of NSPS OOOOb, including cross-reference, paragraph designation, and typographical errors. Table 2 (Cross-Reference, Paragraph Designation, and Typographical Technical Corrections to 40 CFR part 60, subpart OOOOb) includes the sections and paragraphs of each identified error, the corrections being made by this action, and the reasoning for the corrections. The substance of the final rule remains unchanged by correcting these errors, which are technical in nature, and the EPA therefore finds good cause to make these technical corrections to the regulatory text of NSPS OOOOb, without prior notice and comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B).
Table 2—Cross-Reference, Paragraph Designation, and Typographical Technical Corrections to 40 CFR Part 60, Subpart OOOO b
Section and paragraph Technical correction and reason for change 60.5365b(e)(2)(i)(C) Replace “(e)(1)(i)(A)” with “paragraph (e)(2)(i)(A)” to correct an inadvertent cross-reference error and paragraph referencing format. 60.5365b(g)(3) a. Replace “§ 60.5423b(c)” with “§ 60.5423b(e)” to correct an inadvertent cross-reference error; and b. Replace “60.5415b(i)” with “60.5415b(k)” to correct an inadvertent cross-reference error. 60.5365b(g)(4) Replace “60.5415b(i)” with “60.5415b(k)” to correct an inadvertent cross-reference error. 60.5365b(h)(2) a. First sentence: Replace “§ 60.5390b” with “§ 60.5393b” to correct section reference; and b. Fourth sentence: Replace “(h)(2)(ii)” with “paragraph (h)(2)(ii)” to correct paragraph referencing format. 60.5365b(i)(3) introductory text Replace “For purposes of § 60.5397b” with “For purposes of §§ 60.5397b and 60.5398b” to add cross-reference inadvertently omitted. 60.5365b(i)(3)(ii) Second sentence: Replace “for purposes of § 60.5397b” with “for purposes of §§ 60.5397b and 60.5398b” to add cross-reference inadvertently omitted. 60.5370b(a)(1) introductory text Replace “§ 60.5385b(a)” with “§ 60.5385b” to correct paragraph reference. 60.5370b(a)(1)(i) Replace “§ 60.5385b(a)(1) and (d)(3)” with “§ 60.5385b(a)(1)” to remove cross-reference inadvertently included. 60.5370b(a)(4) Replace “§ 60.5400b” with “§ 60.5400b or as an alternative, the requirements in § 60.5401b,” to include an inadvertent cross-reference addition and clarification. 60.5370b(a)(7)(i) Replace “for your reciprocating compressor” with “for your centrifugal compressor” to correct an inadvertent typographical error. 60.5371b(d)(2) introductory text Replace “(d)(6)(i) through (v)” with “(d)(2)(i) through (v)” to correct an inadvertent cross-reference error. 60.5371b(e)(1)(v) Replace “(d)(6)(i) through (v)” with “(d)(2)(i) through (v)” to correct an inadvertent cross-reference error. 60.5376b(a)(1) introductory text First sentence: Replace “(a)(1)(A) and (B)” with “(a)(1)(i) and (ii) and (d) and (e) of this section” to add cross-references inadvertently omitted and to correct paragraph referencing. 60.5376b(g)(4) Replace “§ 60.5415b(f)” with “§ 60.5415b(b)” to correct an inadvertent cross-reference error. 60.5377b(g)(2) Replace “§ 60.5377b(b)(1)” with “§ 60.5377b(b)” to correct paragraph referencing. 60.5380b(a)(5) introductory text a. Replace “Alaska North Slope equipped with seal oil separator” with “Alaska North Slope equipped with sour seal oil separator” to include “sour” which was inadvertently not included. b. Add “of this section” after “(a)(1) and (2)” at the end of the first sentence to correct format inconsistency. 60.5385b(a)(3) introductory text Replace “paragraph (b)” with “paragraph (b) or (c)” in the second sentence to correct cross-references to clarify that either paragraph can be used to conduct follow-up volumetric flow rate measurements. 60.5385b(g) Replace “§ 60.5420b(b)(1), (6), (11) and (12)” with “§ 60.5420b(b)(1), (6), and (11) through (13)” to correct an inadvertent cross-reference error. 60.5386b(c) introductory text Replace “.” with a “,” to correct an inadvertent punctuation error. 60.5393b(b)(6)(ii) a. Replace “§ 60.5420b(c)(15)(ii) and (v)” with “§ 60.5420b(c)(15)(ii) through (iv)” to correct an inadvertent cross-reference error. b. Replace “§ 60.5420b(c)(15)(vi).” with “§ 60.5420b(c)(15)(v) certifying that there is no vapor recovery unit or control device on site.” to correct and clarify cross-reference. 60.5393b(b)(7)(iii) Replace “§ 60.5393b(b)(5)(ii)” with “§ 60.5393b(b)(7)(ii)” to correct an inadvertent cross-reference error. 60.5395b(c)(1)(ii) Replace “§ 60.5420b(b)(6)(viii)” with “§ 60.5420b(b)(8)(vii)” to correct an inadvertent cross-reference error. 60.5395b(c)(2)(iii) Replace “§ 60.5420b(b)(8)(viii)” with “§ 60.5420b(b)(8)(vii)” to correct an inadvertent cross-reference error. 60.5395b(c)(4) Replace “§ 60.5420b(b)(8)(ix)” with “§ 60.5420b(b)(8)(viii)” to correct an inadvertent cross-reference error. 60.5397b(d) introductory text Replace “(d)(1) through (3)” with “(d)(1) and (2)” to correct an inadvertent cross-reference error. 60.5397b(k) Replace “§ 60.5420b(c)(16)” with “§ 60.5420b(c)(14)” to correct an inadvertent cross-reference error. 60.5398b(d)(3)(iii)(A) Delete “g” after “underlying” to remove an inadvertent typographical error. 60.5398b(d)(3)(vi) introductory text Last sentence: Add “must” between “you” and “provide” to correct an inadvertent typographical error. 60.5400b(k) Replace “§ 60.5420b(b)(1) and (11)” with “§ 60.5420b(b)(1) and (11) through (13), as applicable,” to correct inadvertent cross-reference omissions to include all cover, closed vent system and control device requirements. 60.5400b(l) Replace “§ 60.5420b(c)(8), (10) and (12)” with “§ 60.5420b(c)(8) and (10) through (13), as applicable,” to correct inadvertent cross-reference omissions to include all cover, closed vent system and control device requirements. 60.5401b(b) introductory text In the first and last sentence, replace “(b)(2) through (4)” with “(b)(2) through (6)” to correct two inadvertent cross-reference errors. 60.5401b(b)(2) introductory text Replace “(b)(2)(i) through (vi)” with “(b)(2)(i) through (v)” to correct an inadvertent cross-reference error. 60.5401b(b)(5) introductory text Replace “paragraphs (b), (b)(1) and (b)(2)(iv) through (vi)” with “paragraphs (b) introductory text, (b)(1), and (b)(2)(iv) and (v)” to correct an inadvertent cross-reference error and formatting. 60.5401b(c)(5) Replace “paragraph (i)(4)” with “paragraph (i)(6)” to correct an inadvertent cross-reference error. 60.5401b(f) introductory text Replace “(h)(3) through (5)” with “(f)(3) through (5)” to correct an inadvertent cross-reference error. 60.5401b(f)(1) Replace “(h)(3) through (5)” with “(f)(3) through (5)” to correct an inadvertent cross-reference error. 60.5401b(f)(3) introductory text Replace “the requirements in paragraphs (f) of this section” with “the monitoring requirements of paragraph (f) of this section” to include consistent cross-reference specificity. 60.5401b(f)(4) introductory text a. Replace “pump” with “valve” to correct an inadvertent error; and b. Replace “the monitoring requirements in paragraph (f) introductory text of this section” with “the monitoring requirements of paragraph (f) of this section” to include consistent cross-reference specificity. 60.5401b(f)(5) introductory text Replace “the monitoring requirements in paragraph (h)” with “the monitoring requirements in paragraph (f)” to correct an inadvertent cross-reference error and to include consistent cross-reference specificity. 60.5401b(i)(2)(ii) Replace “with (h)(2)(ii)(A), (B) or (C), and (D)” with “with paragraph (i)(2)(ii)(A), (B), or (C), of this section, unless you meet the requirements of paragraph (i)(2)(ii)(D) of this section” to correct an inadvertent cross-reference error and to include that, if complying with paragraph (i)(2)(ii)(D), an owner or operator is not required to comply with the requirements in paragraphs (i)(2)(ii)(A), (B), or (C). 60.5401b(l) Replace “§§ 60.5420b(b)(1), (b)(11), and 60.5422b” with “§ 60.5420b(b)(1) and (11) through (13), as applicable, and § 60.5422b” to correct inadvertent cross-referencing errors to include all cover, closed vent system and control device requirements. 60.5401b(m) Replace “§ 60.5420b(c)(8), (10), (12), and” with “§ 60.5420b(c)(8) and (10) through (13), as applicable, and” to correct recordkeeping referencing to include all cover, closed vent system and control device requirements, as applicable. 60.5402b(d) introductory text Replace “§ 60.5403b(e)” with “§ 60.5403b(d)” to correct cross-reference error. 60.5403b(c) introductory text Replace “§ 60.5401b(b), (c), and (f)” with “§ 60.5401b(b) and (f)” to remove cross-reference to paragraph “(c)” to correct an inadvertent cross-reference error. No detectable emissions (NDE) for pressure relief devices (PRDs) was removed in NSPS OOOOb. 60.5406b(c)(4)(iv) (second paragraph reference) Redesignate second “§ 60.5406b(c)(4)(iv)” paragraph reference as “§ 60.5406b(c)(4)(vi)” to correct paragraph designation. 60.5407b(b)(4) Replace “in paragraph (d)” with “in paragraph (c)” to correct an inadvertent cross-reference error. 60.5410b(b)(4) introductory text Replace “paragraphs (b)(4)(i) through (vii)” with “paragraphs (b)(4)(i) through (vi)” to correct an inadvertent cross-reference error. 60.5410b(c) introductory text Replace “paragraphs (c)(1) through (3)” with “paragraphs (c)(1) through (4)” to correct an inadvertent cross-reference error. 60.5410b(e)(3) Replace “equipe” with “equip” to correct an inadvertent typographical error. 60.5410b(f) introductory text Second sentence: Replace “must perform” with “must also perform” to correct an inadvertent omission. 60.5410b(f)(2) introductory text Replace “(f)(2)(i) through (v)” with “(f)(2)(i) through (iv)” to correct an inadvertent cross-reference error. 60.5410b(g) introductory text Second sentence: Replace “must perform” with “must also perform” to correct an inadvertent omission. 60.5410b(g)(1) introductory text First sentence: Replace “(g)(ii) and (iv)” with “(g)(1)(ii) and (iv)” to correct an inadvertent cross-reference error. 60.5410b(g)(2)(i) Replace “§ 60.5393b(b)(3)” with “§ 60.5393b(b)(5)” to correct an inadvertent cross-reference error. 60.5410b(g)(2)(ii) Replace “§ 60.5393b(b)(4)” with “§ 60.5393b(b)(6)” to correct an inadvertent cross-reference error. 60.5410b(g)(2)(iii) Replace “§ 60.5393b(b)(5)(i)” with “§ 60.5393b(b)(7)” to correct an inadvertent cross-reference error. 60.5410b(h)(12) Replace “§ 60.5400b(h) or § 60.5400b(i)” with “§ 60.5400b(h) or § 60.5401b(i)” to correct an inadvertent cross-reference error. 60.5411b(b)(4) Replace “paragraphs (b)(2)(i) through (iii)” with “paragraphs (b)(2)(i) through (iv)” to correct an inadvertent cross-reference error. 60.5412b(a) introductory text First sentence: a. Replace “§ 60.5377b(f)” with “§ 60.5377b(d) or (f)”; b. Replace “§ 60.5380b(a)(1)” with “§ 60.5380b(a)(1) or (9)”; and c. Replace “§ 60.5393b(b)(1)” with “§ 60.5393b(b)(3)”. These replacements would correct inadvertent cross-reference errors and omissions. 60.5412b(c)(1)(i) Second sentence: Replace “§ 60.5420b(c)(10) and (12)” with “§ 60.5420b(c)(11)” to correct an inadvertent cross-reference error. 60.5412b(d)(4) Second sentence: Replace “§ 5417b(d)(8)(v)” with “§ 60.5417b(d)(8)(v)” to correct an inadvertent cross-reference error. 60.5413b introductory text a. First sentence: Replace “pump affected facilities complying with § 60.5393b(b)(1), or process unit equipment affected facility” with “pump, or process unit equipment affected facilities” to correct language to be consistent with how other emission sources are listed/cited and for added clarity; and b. Last sentence: Replace “pump affected facilities complying with § 60.5393b(b)(1)” with “pump” to correct language to be consistent with how other emission sources are listed/cited. 60.5415b(e)(3) Replace “§ 60.5420b(c)(8), (10), (12), and (15)” with “§ 60.5420b(c)(8), (10) through (12), and (15)” to correct an inadvertent cross-reference error. 60.5415b(f) introductory text First sentence after title: Replace “paragraph (b), (c), (d)(1), (e)(1), (g), (h)(2)(iv), (i) or (j) of this section” with “paragraph (b), (c), (d)(1), (e)(1), (g)(2), (h)(2), (i)(5)(ii)(B) or (j)(12) of this section” to correct inadvertent cross-reference errors. 60.5415b(f)(1)(vii)(A)( 4) Replace “paragraph (f)(1)(vii)(D) of this section” with “paragraph (f)(1)(vii)(A)( 2) of this section” to correct an inadvertent cross-reference error. 60.5415b(h)(3) Replace “§ 60.5420b(b)(1), (7), and (11)(i) through (iv),” with “§ 60.5420b(b)(1), (7), and (11) through (13),” to correct an inadvertent cross-reference error. 60.5415b(i)(3) Replace “requirements of § 60.5395b(c)(1) by” with “requirements of § 60.5395b(c)(1) or (2) by” to correct an inadvertent cross-reference omission. 60.5415b(i)(4) Replace “§ 60.5395b(c)(1)” with “§ 60.5395b(c)(3) and (4)” to correct an inadvertent cross-reference error/omissions. 60.5415b(k)(9) Replace “by § 60.5423b(b) and (d)” with “by § 60.5423b(d)” to remove an inadvertent cross-reference. 60.5415b(l)(4) Replace “§ 60.5420b(c)(16)” with “§ 60.5420b(c)(14)” to correct an inadvertent cross-reference error. 60.5416b(a) introductory text Replace “paragraphs (b)(6) and (7)” with “paragraphs (b)(7) and (8)” to correct an inadvertent cross-reference error. 60.5416b(b)(2) Last sentence: Replace “with this paragraph (b)(2)” with “with paragraph (b)(1)” to correct an inadvertent cross-reference error. 60.5417b(a) First sentence: Replace “§ 60.5393b(b)(1) for your pumps” with “§ 60.5393b(b)(3) for your pumps” to correct an inadvertent cross-reference error. 60.5417b(d)(8) introductory text Revise the first sentence to include commas before and after “other than those listed of this section”. 60.5417b(i)(4) Replace “by § 5412b(d)(4)” with “by § 60.5412b(d)(4)” to correct an inadvertent cross-reference error. 60.5417b(i)(5) Replace “by § 5412b(d)(5)” with “by § 60.5412b(d)(5)” to correct an inadvertent cross-reference error. 60.5417b(j) Replace “in § 60.5420b(c)(1)” with “in § 60.5420b(c)(11)” to correct an inadvertent cross-reference error. 60.5420b(b)(1)(v)(A) Replace “paragraph (b)(v) of” with “paragraph (b)(1)(v) of” to correct an inadvertent cross-reference error. 60.5420b(b)(1)(v)(B) Replace “paragraph (b)(v) of” with “paragraph (b)(1)(v) of” to correct an inadvertent cross-reference error. 60.5420b(b)(5)(iii) Replace paragraph with “If required to comply with § 60.5380b(a)(2) or (3), the information specified in paragraphs (b)(11)(i) through (iv) of this section, as applicable.” This adds “or (3)” and “, as applicable” to correct inadvertent cross-reference omission and to add “as applicable” to clarify that not all cited requirements may apply. 60.5420b(b)(5)(vi) Replace “§ 60.5380b(a)(4) or (5)” with “§ 60.5380b(a)(4), (5) or (6)” to correct an inadvertent cross-reference error. 60.5420b(b)(6)(i) Replace “May 7, 2024, or since the previous” with “May 7, 2024, since the previous” to correct grammar. 60.5420b(b)(6)(iv) Revise paragraph to indicate that, if you are complying with § 60.5385b(d)(1) or (2), the information in paragraphs (b)(11)(i) through (iv) of the section apply and if you are complying by routing emissions to a control device, as required in § 60.5385b(d)(2), the information in paragraph (b)(11)(v) of the section applies. These revisions correct cross-reference omissions. 60.5420b(b)(7)(x) Replace “paragraphs (b)(7)(ii)(B)” with “paragraphs (b)(7)(vi) and (vii)” to correct an inadvertent cross-reference error. 60.5420b(b)(10)(ii) Replace “§ 60.5393b(b)(3)” with “§ 60.5393b(b)(5)” to correct an inadvertent cross-reference error. 60.5420b(b)(10)(iii) Replace “§ 60.5393b(b)(4)” with “§ 60.5393b(b)(6)” to correct an inadvertent cross-reference error. 60.5420b(b)(10)(iv) Replace “§ 60.5393b(b)(5)” with “§ 60.5393b(b)(7)” to correct an inadvertent cross-reference error. 60.5420b(b)(10)(v)(A) Replace “§ 60.5393b(b)(1) or (3)” with “§ 60.5393b(b)(2), (3), or (5)” to correct inadvertent cross-reference errors. 60.5420b(b)(10)(v)(B) a. Replace first mention of “§ 60.5393b(b)(1) or (3)” with “§ 60.5393b(b)(2), (3), or (5), as applicable,” to correct inadvertent cross-reference errors/omissions; and b. Replace second mention of “§ 60.5393b(b)(1) or (3)” with “§ 60.5393b(b)(2), (3), or (5)” to correct inadvertent cross-reference errors/omissions. 60.5420b(b)(10)(vii) a. Replace “§ 60.5393b(b)(1) or (3)” with “§ 60.5393b(b)(3) or (5)” to correct an inadvertent cross-reference error; and b. Replace “paragraph (b)(11) of this section” with “paragraphs (b)(11)(i) through (v) of this section” to correct an inadvertent cross-reference error. 60.5420b(b)(11)(v)(L) Change both references to “§ 60.5415b(f)(x)” to “§ 60.5415b(f)(1)(x)” to correct inadvertent cross-reference errors. 60.5420b(c)(2)(i)(A) Last sentence: Change “records all of the” to “records of all the” to correct an inadvertent typographical error. 60.5420b(c)(2)(ii)(C) Replace “taken minimize” with “taken to minimize” to correct an inadvertent typographical error. 60.5420b(c)(2)(ii)(D) Replace “documentation of best management practice plans steps were not followed” with “documentation of best management practice plan steps not followed” to correct a typographical error. 60.5420b(c)(3)(iv)(B) a. Replace “§ 60.5380b” with “§ 60.5377b” to correct an inadvertent cross-reference error; and b. Replace “paragraph (c)(11)” with “paragraphs (c)(11) and (13)” to correct an inadvertent cross-reference omission. 60.5420b(c)(4)(iii) introductory text a. Replace “self-contained wet seal compressor, or” with “self-contained wet seal compressor, centrifugal compressor equipped with sour seal oil separator and capture system, or” to correct an inadvertent reference omission; and b. Replace “§ 60.5380b(a)(4) and (5)” with “§ 60.5380b(a)(4), (5) or (6)” to correct an inadvertent cross-reference omission. 60.5420b(c)(4)(iii)(C)( 2) Replace “§ 60.5380b(a)(5)” with “§ 60.5380b(a)(4) through (6)” to correct inadvertent cross-reference omissions. 60.5420b(c)(5) introductory text Replace “(c)(8), (c)(10) and (c)(12) of this section” with “(c)(8) through (13) of this section” to correct inadvertent cross-reference omissions. 60.5420b(c)(7)(iv)(A) Replace “paragraph (c)(11)” with “paragraphs (c)(11) and (13)” to correct an inadvertent cross-reference omission. 60.5420b(c)(11) introductory text Revised to correct inadvertent cross-reference errors/omissions. 60.5420b(c)(11)(v) Replace both references to “§ 60.5415b(f)(x)” with “§ 60.5415b(f)(1)(x)” to correct inadvertent cross-reference errors. 60.5420b(c)(15)(iv) Replace “§ 60.5393b(b)(3)” with “§ 60.5393b(b)(5)” to correct an inadvertent cross-reference error. 60.5420b(c)(15)(v) a. First sentence: Replace “you must retain a record of your certification required under § 60.5393(b)(4)” with “you must retain a record of your certification required under § 60.5393(b)(6)” to correct an inadvertent cross-reference error; and b. Second sentence: Replace “paragraphs (c)(15)(ii), (iii) or (iv) of this section” with “paragraph (c)(15)(ii) and paragraph (c)(15)(iii) or (iv) of this section” to correct an inadvertent omission to clarify that complying with paragraph (c)(15)(ii) is not conditional. 60.5420b(d) introductory text Third sentence: Replace “paragraphs (g)(1) and (2) of this section” with “paragraphs (d)(1) and (2) of this section” to correct an inadvertent cross-reference error. 60.5421b introductory text First sentence: Replace “paragraphs (b)(1) through (16) of this section” with “paragraphs (b)(1) through (17) of this section” to correct an inadvertent cross-reference error. 60.5421b(b) introductory text Replace “paragraphs (b)(1) through (16)” with “paragraphs (b)(1) through (17)” to correct an inadvertent cross-reference error. 60.5421b(b)(11)(vi) Change paragraph designation to “(b)(11)(iv)”. Newly designated 60.5421b(b)(11)(iv) Replace “paragraph (b)(11)(vi)(A) through (C)” with “paragraph (b)(11)(iv)(A) through (C)” to conform cross-reference with corrected paragraph designation (see above). 60.5424b(e)(6) Replace “§ 60.5398b(c)(1)(ii)(D)” with “§ 60.5398b(c)(1)(iv)(D)” to correct an inadvertent cross-reference error. 60.5430b “ No identifiable emissions ” definition Italicize “emissions” in “ No identifiable emissions” to correct an inadvertent inconsistency error to make it clear that the phrase being defined is inclusive of “emissions.” 60.5430b “ Storage vessel” definition Subparagraph (1) of definition, second sentence: Replace “§ 60.5420b(c)(5)(iv)” with “§ 60.5420b(c)(7)(v)” to correct an inadvertent cross-reference error. Table 3 to Subpart OOOOb of Part 60—Required Minimum Initial SO 2 Emission Reduction Efficiency (Z i ) Table 3 is corrected by revising mathematical symbols where “greater than or equal to” and “less than or equal to” symbols were not included. Table 4 to Subpart OOOOb of Part 60—Required Minimum SO 2 Emission Reduction Efficiency (Z c ) Table 4 is corrected by revising mathematical symbols where “greater than or equal to” and “less than or equal to” symbols were not included. 2. Clarifying Technical Corrections
This action also makes technical corrections to clarify language in the regulatory text that was erroneously included (or in some cases, erroneously omitted). Table 3 (Clarifying Technical Corrections to 40 CFR part 60, subpart OOOOb) includes the sections and paragraphs of each identified error, the corrections being made by this action, and the reasoning for the corrections. These clarifying technical corrections do not substantively alter the regulatory text in a way that affects the regulated community or the public because they do not change any substantive standard—they simply clarify erroneous language and/or omissions. The substance of the final rule remains unchanged by making these clarifying technical corrections and therefore, the EPA finds good cause to make the clarifying technical corrections to the regulatory text of NSPS OOOOb set forth in Table 3, without prior notice and comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B).
Table 3—Clarifying Technical Corrections to 40 CFR Part 60, Subpart OOOO b
Section and paragraph Clarifying technical correction and reason for change 60.5371b(c)(4) Replace “within 50 meters of the latitude and longitude coordinates of the super-emitter event.” with “within 50 meters of the latitude and longitude coordinates of the super-emitter event, if available.” to correct an inadvertent omission. “If available” is included on 89 FR 16880 in the Final Rule preamble discussion of third-party notifications that must be submitted to the Super Emitter Program Portal. This change is consistent with the Final Rule preamble discussion. 60.5385b(d)(3) Remove “initial” before “startup” to be consistent with other referencing in the Final Rule and 89 FR 16896 of the Final Rule preamble. 60.5386b(a)(1) introductory text Second sentence: Add “or wet” after “dry” to correct an inadvertent omission. See 89 FR 17058, § 60.5386b(a) introductory text Final Rule regulatory language which indicates that requirements also apply to wet seal compressors. This correction is consistent with the cited Final Rule regulatory language. 60.5398b(b)(5)(ii)(A) Revised to clarify that monitoring surveys must be conducted for all the fugitive emissions components in an affected facility using either OGI or EPA Method 21 to appendix A-7 of this part; and that the procedures in your monitoring plan must be followed when conducting the survey. These revisions correct an inadvertent omission of the specific survey methods and procedures required. See 89 FR 16874 Final Rule preamble periodic screening discussion. These clarifying correction are consistent with the Final Rule preamble discussion. 60.5398b(b)(5)(iii)(A) Revised to clarify that monitoring surveys must be conducted for all fugitive emissions components located within a 4-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of part 60. These revisions correct an inadvertent omission of the specific survey methods required. See 89 FR 16874 Final Rule preamble periodic screening discussion. This correction is consistent with the Final Rule preamble discussion. 60.5398b(b)(5)(iv)(A) a. Delete “the” before “all the fugitive emissions” in the first sentence to omit an inadvertent typographical error; and b. Add “using either OGI or EPA Method 21 to appendix A-7 of this part” after “confirmed detection” at the end of the first sentence to correct an inadvertent omission. See 89 FR 16874 Final Rule preamble periodic screening discussion. This correction is consistent with the Final Rule preamble discussion. 60.5400b(c)(1) Replace “5 calendar days using the methods” with “5 calendar days using OGI in accordance with Appendix K or the methods” to correct an inadvertent omission that specifically clarifies that screening using OGI in accordance with Appendix K is an option, consistent with the Final Rule preamble. See 89 FR 16899 to 16900 Final Rule preamble discussion. This correction is consistent with the Final Rule preamble discussion. 60.5401b(h)(1) a. Add “all connectors” between “and” and “in light” to include referencing consistency; and b. Add the following sentence to clarify what constitutes a leak for connectors: “If an instrument reading greater than or equal to 500 ppmv is measured, a leak is detected.” These corrections address inadvertent language/omission errors. Change “a.” is consistent with language at the beginning of the sentence that states “monitor all connectors in gas/vapor service” (see 89 FR 17077). Change “b.” includes language that indicates what constitutes a leak based on Method 21, consistent with other statements in the Final Rule preamble and regulatory text ( e.g., see 89 FR 17076). 60.5410b(c)(2)(i) Replace “another well, and submit this documentation in the initial annual report” with “another well, maintain the documentation in accordance with § 60.5377(g), and submit this documentation in the initial annual report as required by paragraph (c)(4) of this section” to correct an inadvertent cross-reference error and omission of a cross-reference to the requirement to maintain documentation. See 89 FR 17084 for the Final Rule regulatory text requirements. These changes are consistent with the Final Rule regulatory text requirements. 60.5410b(c)(2)(ii) Replace “(ii) Submit the certification as required by § 60.5377b(g)” with “(ii) Maintain a copy of the certification and submit the certification as required by § 60.5377b(g)” to correct the language to clarify that an owner or operator needs to maintain a copy of the certification. See 89 FR 17084 for the Final Rule regulatory text These changes are consistent with the Final Rule regulatory text. 60.5410b(d)(2) Replace “closed vent system that meets” with “closed vent system to a process that meets” in the last sentence to clarify that requirements apply when emissions are routed to a process and to be consistent with the second sentence of the paragraph. See 89 FR 17084 for the Final Rule regulatory text. This change is consistent with the Final Rule regulatory text. 60.5410b(d)(6) introductory text Delete last sentence to correct an inadvertent cross-reference error. For clarity, rather than correct reference to more broadly apply to paragraph (a), sections (d)(6)(i) through (iii) were revised to more-specifically clarify requirements for each of the three types of centrifugal compressors. (See below.) See 89 FR 16891 to 16892 of the Final Rule preamble for a discussion regarding centrifugal compressor annual volumetric flow measurement requirements. These changes are consistent with the Final Rule preamble discussion. 60.5410b(d)(6)(i) Add the following sentence to more-specifically clarify and correct an inadvertent omission of referencing to the requirements that apply to self-contained wet seal centrifugal compressors: “You must conduct your initial annual volumetric measurement as required by § 60.5380b(a)(4).” For clarity, rather than correct reference to more broadly apply to paragraph (a), sections (d)(6)(i) through (iii) were revised to more-specifically clarify requirements for each of the three types of centrifugal compressors. See 89 FR 16891 to 16892 of the Final Rule preamble for a discussion regarding centrifugal compressor annual volumetric flow measurement requirements. These changes are consistent with the Final Rule preamble discussion. 60.5410b(d)(6)(ii) Add the following sentence to more-specifically clarify and correct an inadvertent omission of referencing to the requirements that apply to centrifugal compressors on the Alaska North Slope equipped with sour seal oil separator and capture systems: “You must conduct your initial annual volumetric measurement as required by § 60.5380b(a)(5).” For clarity, rather than correct reference to more broadly apply to paragraph (a), sections (d)(6)(i) through (iii) were revised to more-specifically clarify requirements for each of the three types of centrifugal compressors. See 89 FR 16891 to 16892 of the Final Rule preamble for a discussion regarding centrifugal compressor annual volumetric flow measurement requirements. These changes are consistent with the Final Rule preamble discussion. 60.5410b(d)(6)(iii) a. Replace “dry seal compressor” with “dry seal centrifugal compressor” for centrifugal compressor referencing consistency; and b. Add the following sentence to more-specifically clarify and correct an inadvertent omission of referencing to the requirements that apply to dry seal centrifugal compressors: “You must conduct your initial annual volumetric measurement as required by § 60.5380b(a)(6).” For clarity, rather than correct reference to more broadly apply to paragraph (a), sections (d)(6)(i) through (iii) were revised to more-specifically clarify requirements for each of the three types of centrifugal compressors. See 89 FR 16891 to 16892 of the Final Rule preamble for a discussion regarding centrifugal compressor annual volumetric flow measurement requirements. These changes are consistent with the Final Rule preamble discussion. 60.5412b(a) introductory text Second sentence: Replace “As an alternative to paragraphs (a)(1) through (a)(3) of this section, you may install a control device model tested under § 60.5413b(d)” with “As an alternative to paragraph (a)(1) of this section, you may install a combustion control device model tested under § 60.5413b(d)” to correct an inadvertent omission that clarifies that control device model test requirements are for combustion control device models. See 89 FR 17093 for combustion device model testing regulatory text requirements. This change is consistent with the regulatory text requirements. 60.5415b(d)(2) Revised paragraph to clarify the volumetric monitoring compliance options for each of the centrifugal compressor types. Volumetric monitoring requirements are the same for all centrifugal compressors and are repeated and referenced under differing subparagraphs of paragraph (a). See 89 FR 16891 to 16892 for a Final Rule preamble discussion of centrifugal compressor requirements. These changes are consistent with the Final Rule preamble discussion. 60.5415b(e)(1) Replace “you must continuously” with “you must route emissions through a closed vent system and continuously” to correct an inadvertent omission and to clearly state that routing emissions through a closed vent system “and” complying with the requisite closed vent system requirements is required when routing emissions to a process. This change corrects an inadvertent omission and is consistent with the Final Rule regulatory text for similar requirements ( e.g., see 89 FR 17181, 17182, and 17184 for similar requirements for liquids unloading, associated gas, centrifugal compressors, and reciprocating compressors). 60.5415b(h)(1)(i) Replace “must comply” with “must route emissions through a closed vent system and continuously comply” to correct an inadvertent omission and to clearly state that routing emissions through a closed vent system “and” continuously complying with the requisite closed vent system requirements is required when routing emissions to a process. This change corrects an inadvertent omission and is consistent with the Final Rule regulatory text for similar requirements ( e.g., see 89 FR 17181, 17182, and 17184 for similar requirements for liquids unloading, associated gas, centrifugal compressors, and reciprocating compressors). 60.5415b(h)(2) Replace “must comply” with “must route emissions to a control device through a closed vent system and continuously comply” to correct an inadvertent omission and to clearly state that routing emissions through a closed vent system “and” continuously complying with the requisite closed vent system requirements is required when routing emissions to a control device. This change corrects an inadvertent omission. This change corrects an inadvertent omission and is consistent with the Final Rule regulatory text for similar requirements ( e.g., see 89 FR 17181, 17182, and 17184 for similar requirements for liquids unloading, associated gas, centrifugal compressors, and reciprocating compressors). 60.5415b(i)(2)(iii) Replace “4 tpy or greater and the increase” with “4 tpy or greater or methane emissions from your storage vessel affected facility increase to 14 tpy or greater and the increase” to correct an inadvertent omission. See 89 FR 16896 to 16897 for a Final Rule preamble discussion of storage vessel requirements. This change is consistent with the Final Rule preamble discussion. Table 5 to Subpart OOOOb of Part 60—Applicability of General Provisions to Subpart OOOOb; General provisions citation § 60.8 Revise second sentence of “Explanation” column by replacing “Performance testing is required for control devices used on storage vessels, centrifugal compressors, process controllers, and pumps complying with § 60.5393b(b)(1), except” with “Performance testing is required for control devices used on wells, storage vessels, centrifugal compressors, reciprocating compressors, process controllers, and pumps, as applicable, except” to correct inadvertent affected facility omissions and to correct the referencing for pumps to exclude “complying with § 60.5393b(b)(1)” to be consistent with other emission source referencing. These changes correct the listing of affected facilities where the Final Rule includes control device performance testing requirements to comply and to clarify that the performance test requirements apply conditionally ( i.e., performance test requirements would not apply where an affected facility complies with the final rule by meeting a compliance option that does not require control device performance testing). The EPA finds good cause to make these technical corrections and clarifications to NSPS OOOOb, identified above in Tables 2 and 3, without prior notice and comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B).
A red line and strike-out version of the corrected regulatory language for NSPS OOOOb is available in Docket ID No. EPA-HQ-OAR-2021-0317.
D. Technical Corrections for EG OOOOc
1. Cross-Reference, Paragraph Designation, and Typographical Technical Corrections
Following signature of the final rule, stakeholders and the Office of the Federal Register brought to the Agency's attention, and the EPA itself identified, inadvertent errors, including cross-reference, paragraph designation, and typographical errors, in the regulatory text of NSPS OOOOc. Table 4 (Cross-Reference, Paragraph Designation, and Typographical Technical Corrections to 40 CFR part 60, subpart OOOOc) includes the sections and paragraphs of the identified errors, the corrections being made, and the reasoning for the corrections. For the same reasons explained in Section II.C.1 discussing such corrections for NSPS OOOOb, the EPA finds good cause to make these technical corrections to the regulatory text of EG OOOOc without prior notice and comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B).
Table 4—Cross-Reference, Paragraph Designation, and Typographical Corrections to 40 CFR Part 60, Subpart OOOO c
Section and paragraph Technical correction and reason for change 60.5370c(b) Replace “§§ 60.5380c through 60.5382c” with “§§ 60.5379c through 60.5381c” to correct an inadvertent cross-reference error. 60.5374c(b) Replace “§ 60.5367c” with “§ 60.5368c” to correct an inadvertent cross-reference error. 60.5375c(a)(3) Replace “§ 60.14c” with “§ 60.14(e)” to correct an inadvertent cross-reference error. 60.5386c(e)(2)(i)(C) Replace “(e)(1)(i)(A)” with “paragraph (e)(2)(i)(A) of this section” to correct an inadvertent cross-reference error. 60.5388c(a)(1) First sentence: Replace “EPA under paragraph (e) of this section” with “EPA under paragraph (b) of this section” to correct an inadvertent cross-reference error. 60.5388c(a)(2) a. Replace paragraph (a)(2) by adding paragraph (a)(3) regulatory text to paragraph (a)(2); and b. Replace “paragraph (a)(2)” referencing to state “this paragraph (a)(2)”. These corrections correct inadvertent paragraph designation and cross-reference errors. 60.5388c(a)(3) Remove paragraph (a)(3). The regulatory text of (a)(3) was added to paragraph (a)(2) (see above). 60.5388c(a)(4) Change paragraph designation to (a)(3) to correct a typographical error. 60.5388c(b)(1)(v) Replace “paragraphs (a)(3)(i) through (v)” with “paragraphs (a)(2)(i) through (v)” to correct an inadvertent cross-reference error. 60.5390c(a)(1) introductory text Replace “paragraphs (a)(1)(A) and (B)” with “paragraphs (a)(1)(i) and (ii) and (d) and (e)” to correct inadvertent omissions of cross-references and to correct paragraph referencing. 60.5391c(b)(2)(i) Third sentence: Replace “§ 60.5420c(c)(2)(ii)” with “§ 60.5420c(c)(2)(iv)” to correct an inadvertent cross-reference error. 60.5391c(b)(2)(ii) Third sentence: Replace “§ 60.5391c(b)(1)” with “§ 60.5391c(b)(2)” to correct an inadvertent cross-reference error. 60.5391c(b)(2)(iv) Replace “§ 60.5420c(c)(3)(ii)” with “§ 60.5420c(c)(2)(iv)” to correct an inadvertent cross-reference error. 60.5391c(c) introductory text a. Second sentence: Replace “§ 60.5412c (a), (b) and (c)” with “§ 60.5412c” to correct an inadvertent cross-reference error; and b. Last sentence: Replace “§ 60.5420c(c)(3)” with “§ 60.5420c(c)(2)” to correct an inadvertent cross-reference error. 60.5391c(c)(3) Replace “For (a)(1) and (b)(1) of this section, through the duration” with “For wells complying with paragraph (a)(1) of this section, for the duration” to correct an inadvertent addition of a cross-reference and to correct a typographical error. 60.5391c(d) introductory text Last sentence: Replace “§ 60.5420c(c)(3)” with “§ 60.5420c(c)(2)” to correct an inadvertent cross-reference error. 60.5391c(e)(2) Replace “§ 60.5410c(c)(3)” with “§ 60.5420c(c)(2)”, and “§ 60.5410c(b)(3)” with “§ 60.5420c(b)(3)” to correct inadvertent cross-reference errors. 60.5391c(e)(3) Replace “paragraph (a)(d)(1)” with “paragraph (e)(1)” to correct an inadvertent cross-reference error. 60.5391c(g) Replace “§ 60.5415c(b)(3)” with “§ 60.5415c(b)” to correct an inadvertent cross-reference error. 60.5391c(h) Replace “perform the required recordkeeping and reporting as required by § 60.5420c(b)(3),” with “perform the recordkeeping and reporting as required by § 60.5420c(b)(1), (3), and (10) through (12)” to correct inadvertent cross-reference omissions and to eliminate redundancy of the term “required”. 60.5393c(g) Replace “60.5420c(b)(1), (5), (10) and (11), as applicable; and the recordkeeping requirements as specified in § 60.5420c(c)(4) and (7) through (11)” with “§ 60.5420c(b)(1) and (5) and (10) through (12), as applicable; and the recordkeeping requirements as specified in § 60.5420c(c)(4) and (7) through (12)” to correct inadvertent cross-reference omissions. 60.5394c(b)(3) Replace “emissions through a closed vent system to a control device through a closed vent system” with “emissions to a control device through a closed vent system” to correct inadvertent redundancy. 60.5395c(b)(6)(ii) Replace “in § 60.5420c(c)(14)(vi)” with “in § 60.5420c(c)(14)(v) certifying that there is no vapor recovery unit or control device on site” to correct an inadvertent cross-reference error and to state the corrected cross-reference requirements. 60.5395c(b)(7)(iii) Replace “I further certify that the assessment was conducted and this report was prepared pursuant to the requirements of § 60.5395c(b)(5)(ii)” with “I further certify that the assessment was conducted and this report was prepared pursuant to the requirements of § 60.5395c(b)(7)(ii)” to correct an inadvertent cross-reference error. 60.5396c(a)(3) introductory text First sentence: Replace “paragraphs (a)(3)(i) through (iii)” with “paragraphs (a)(3)(i) and (ii)” to correct an inadvertent cross-reference error. 60.5396c(c)(1)(ii) Replace “required in § 60.5420c(b)(7)(viii)” with “required in § 60.5420c(b)(7)(vii)” to correct an inadvertent cross-reference error. 60.5396c(c)(4) Replace “required in § 60.5420c(b)(7)(ix)” with “required in § 60.5420c(b)(7)(viii)” to correct an inadvertent cross-reference error. 60.5398c(c)(5)(ii) a. Second sentence: Replace “beginning the period in paragraph (b)(5)(iii) of this section” with “beginning the period in paragraph (c)(5)(iii) of this section” to correct an inadvertent cross-reference error; and b. Last sentence: Replace “paragraph (b)(5)(iii) of this section” with “paragraph (c)(5)(iii) of this section” to correct an inadvertent cross-reference error. 60.5400c(a)(1) Last sentence: Replace “see § 60.17” with “see § 60.17” to address a typographical error (added a space between “see” and “§ ”). 60.5400c(k) Replace “§ 60.5420c(b)(1) and (10)” with “§ 60.5420c(b)(1) and (10) through (12), as applicable,” to correct inadvertent cross-reference omissions. 60.5400c(l) Replace “§ 60.5420c(c)(7), (9), and (11)” with “§ 60.5420c(c)(7) and (9) through (12), as applicable,” to correct inadvertent cross-reference omissions. 60.5401c(a) introductory text First sentence: Replace “requirements in paragraphs (b)” with “requirements in paragraph (b)” to correct a typographical and a format error. 60.5401c(b) introductory text First and last sentence: Replace “in paragraphs (b)(2) through (4)” with “in paragraphs (b)(2) through (6)” to correct inadvertent cross-reference errors. 60.5401c(b)(2) introductory text Replace “paragraphs (b)(2)(i) through (vi) of this section” with “paragraphs (b)(2)(i) through (v) of this section” to correct an inadvertent cross-reference error. 60.5401c(b)(5) introductory text Replace “(b)(1) and (b)(2)(iv) through (vi) of this section” with “(b)(1) and (b)(2)(iv) and (v) of this section” to correct an inadvertent cross-reference error. 60.5401c(c)(5) Replace “except as provided in paragraph (i)(4) of this section” with “except as provided in paragraph (i)(6) of this section” to correct an inadvertent cross-reference error. 60.5401c(f) introductory text Replace “paragraphs (h)(3) through (5)” with “paragraphs (f)(3) through (5)” to correct an inadvertent cross-reference error. 60.5401c(f)(1) Replace “paragraphs (h)(3) through (5)” with “paragraphs (f)(3) through (5)” to correct an inadvertent cross-reference error. 60.5401c(f)(3) introductory text Replace “the requirements in paragraphs (f) of this section” with “the monitoring requirements of paragraph (f) of this section” to include cross-reference specificity to include the exemption from the monitoring requirements. 60.5401c(f)(4) introductory text Replace “unsafe-to-monitor pump” with “unsafe-to-monitor valve” to correct a typographical error. 60.5401c(f)(5) introductory text Replace “paragraph (h) of this section” with “paragraph (f) of this section” to correct inadvertent cross-reference error. 60.5401c(l) Replace “§ 60.5420c(b)(1) and (b)(10)” with “§ 60.5420c(b)(1) and (10) through (12), as applicable,” to correct inadvertent cross-reference omissions. 60.5401c(m) Replace “§ 60.5420c(c)(7), (9), (11), and” with “§ 60.5420c(c)(7) and (9) through (12), as applicable, and” to correct inadvertent cross-reference omissions. 60.5402c(d) introductory text Replace “60.5403c(e)” with “60.5406c(d)” to correct an inadvertent cross-reference error. 60.5405c(a) introductory text a. Replace “§ 60.5393c(a)(2)(iv)” with “§ 60.5393c(a)” to correct an inadvertent cross-reference error; and b. Replace “§ 60.5392c(a)(2)(i)(A)” with “§ 60.5392c(a)(1) or (2)” to correct an inadvertent cross reference error; and c. Add an “s” to “paragraph” introducing “(a)(1) and (2)” to correct a typographical error. 60.5405c(a)(2) Replace “§ 60.5403c(b)(1) and (2)” with “§ 60.5406c(b)(1) and (2)” to correct an inadvertent cross-reference error. 60.5405c(c)(4)(ii) Add space between “sensor(s)” and “must” to correct a typographical error. 60.5406c(c) introductory text Replace “§ 60.5401c(b), (c), and (f)” with “§ 60.5401c(b) and (f)” to correct an inadvertent cross-reference error. 60.5410c(a)(3)(i) Replace “§ 60.5390c(d)” with “§ 60.5390c(c)” to correct an inadvertent cross-reference error. 60.5410c(a)(4)(iv) Replace “You must conduct the initial” with “Conduct the initial” to conform with other subparagraphs. 60.5410c(a)(4)(v) Replace “You must install and” with “Install and” to conform with other subparagraphs. 60.5410c(a)(4)(vi) a. Replace “You must maintain the” with “Maintain the” to conform with other subparagraphs; and b. Replace “by § 60.5420c(b)(11) through (13), as applicable” with “by § 60.5420c(b)(10) through (12), as applicable” to correct inadvertent cross-reference errors. 60.5410c(b)(1) Replace “§ 60.5420c(c)(2)(i) and submit the information required by § 60.5420c(b)(3)(i) through (iv)” with “§ 60.5420c(c)(2)(i) and (ii), as applicable, and submit the information required by § 60.5420c(b)(3)(i) through (v)” to correct inadvertent cross-reference errors/omissions. 60.5410c(b)(2) Replace “initial annual report, and” with “initial annual report as required by paragraph (b)(5) of this section, and” to correct an inadvertent cross-reference omission. 60.5410c(b)(3) a. First sentence: Replace “§ 60.5391c(e)(1) and” with “§ 60.5391c(b)(2), maintain the documentation in accordance with § 60.5391c(b)(2)(iv), and” to correct inadvertent cross-reference error/omission; and b. Second sentence: Replace “initial annual report, and” with “initial annual report as required by paragraph (b)(5) of this section, and” to correct an inadvertent cross-reference omission. 60.5410c(b)(4) introductory text Replace “§ 60.5391c(b), you must comply with paragraphs (b)4)((i) through (iv) of this section” with “§ 60.5391c(b) or (c), you must comply with paragraphs (b)(4)(i) through (vi) of this section.” to correct inadvertent cross-reference error/omission, to correct the format of the paragraph reference, and to add punctuation (a period). 60.5410c(b)(4)(v) Replace “§ 60.5417c(a) through (g)” with “§ 60.5417c(a) through (i)” to correct an inadvertent cross-reference error. 60.5410c(b)(4)(vi) Replace “60.5420c(c)(2)(ii) and” with “60.5420c(c)(2)(ii) and (v), and” to correct an inadvertent cross-reference omission. 60.5410c(e) introductory text Second sentence: a. Replace “If you change compliance methods, you must perform” with “If you change compliance methods, you must also perform” to correct an inadvertent omission to clarify that performing applicable compliance demonstrations is an additional requirement when there is a change in compliance methods. b. Replace “records required by paragraph (e)(1)(i) or (ii) of this section, for” with “records required by paragraph (e)(1)(i) or (ii) of this section, as applicable, for” to correct an inadvertent omission to indicate that records required are dependent on the new compliance method. 60.5410c(e)(1) introductory text Replace “paragraph (e)(3) of this section” with “paragraphs (e)(1)(i) and (ii) of this section” to correct an inadvertent cross-reference error. 60.5410c(e)(2)(iv)(C) Replace “continuous compliance requirements of § 60.5415c(g)” with “continuous compliance requirements of § 60.5415c(e)” to correct an inadvertent cross-reference error. 60.5410c(e)(2)(iv)(D) Replace “§ 60.5417c(a) through (g), as applicable” with “§ 60.5417c(a) through (i), as applicable” to correct an inadvertent cross-reference error. 60.5410c(f)(1) introductory text Second sentence: “paragraphs (f)(1)(i) and (v) of this section” with “paragraphs (f)(1)(i) through (v) of this section” to correct inadvertent cross-reference omissions. 60.5410c(f)(2)(iii) Replace “§ 60.5395c(b)(5)(i)” with “§ 60.5395c(b)(7)(i)” to correct an inadvertent cross-reference error. 60.5410c(f)(3) Replace “§ 60.5420c(b)(1) and (9)” with “§ 60.5420c(b)(1) and (9) through (12), as applicable” to correct inadvertent cross-reference omissions. 60.5410c(g)(11)(iii) Replace “§ 60.5415c(d)” with “§ 60.5415c(e)” to correct an inadvertent cross-reference error. 60.5410c(g)(11)(v) Replace “§ 60.5417c(a) through (g)” with “§ 60.5417c(a) through (i)” to correct an inadvertent cross-reference error. 60.5410c(g)(12) Replace “§ 60.5400c(h) or § 60.5400c(i)” with “§ 60.5400c(h) or § 60.5401c(i)” to correct an inadvertent cross-reference error. 60.5410c(h)(4) Replace “continuous compliance requirements of § 60.5415c(h)” with “continuous compliance requirements of § 60.5415c(e)” to correct an inadvertent cross-reference error. 60.5410c(h)(6) Replace “§ 60.5417c(a) through (g)” with “§ 60.5417c(a) through (i)” to correct an inadvertent cross-reference error. 60.5411c(b)(4) Replace “paragraphs (b)(2)(i) through (iii) of this section” with “paragraphs (b)(2)(i) through (iv) of this section” to correct an inadvertent cross-reference error. 60.5412c(a) introductory text a. Replace “§ 60.5391c(b) for your well designated facility with associated gas” with “§ 60.5391c(b) or (c) for your well designated facility with associated gas” to correct an inadvertent cross-reference omission; and b. Replace “§ 60.5395c(b)(1) for your pumps designated facility” with “§ 60.5395c(b)(3) for your pumps designated facility” to correct an inadvertent cross-reference error. 60.5412c(a)(3)(iii) and (iv) For variables “NHVcz” and “NHVdil” correct so that “cz” and “dil” are subscripts to correct inadvertent typographical errors. 60.5412c(c)(1)(i) Replace “§ 60.5420c(c)(9) and (11)” with “§ 60.5420c(c)(10)” to correct an inadvertent cross-reference error. 60.5413c introductory text a. First sentence: Replace “process controller, pump designated facilities complying with § 60.5393c(b)(1), or process unit equipment designated facility” with “process controller, pump, or process unit equipment designated facilities” to be consistent with other referencing in the paragraph; and b. Last sentence: Replace “pump designated facilities complying with § 60.5393c(b)(1)” with “pump” to be consistent with other referencing in the paragraph. 60.5415c(a) a. Second sentence: Replace “each gas well liquids unloading well affected facility” with “each gas well liquids unloading well designated facility” to correct an inadvertent typographical error; and b. Last sentence: Replace “specified in paragraph (f) of this section and maintain the records in § 60.5420c(c)(7), (9), and (11)” with “specified in paragraph (e) of this section, maintain the reports in § 60.5420c(b)(10)(i) through (iv), and maintain the records in § 60.5420c(c)(7), (9), and (11)” to correct an inadvertent cross-reference error and omissions. 60.5415c(c)(2) First sentence: Replace “§ 60.5416c(a) and (b)” with “§ 60.5416c” to correct an inadvertent referencing error (there are only two paragraphs in § 60.5416c ( i.e., the referenced (a) and (b) paragraphs)). 60.5415c(d)(1) a. First sentence: Replace “requirements of § 60.5395c(b)(1) or (3), you must continuously comply with the closed vent requirements of § 60.5416c(a) and (b)” with “requirements of § 60.5395c(b)(2) or (3), you must continuously comply with the closed vent system requirements of § 60.5416c” to correct an inadvertent referencing error (there are only two paragraphs in § 60.5416c ( i.e., the referenced (a) and (b) paragraphs)), and to correct an inadvertent cross-reference error; and b. Last sentence: Replace “requirements in paragraph (d) of this section” with “requirements in paragraph (e) of this section” to correct an inadvertent cross-reference error. 60.5415c(d)(2) Replace “§ 60.5420c(b)(1), and (9) through (12)” with “§ 60.5420c(b)(1) and (9) and (b)(10)(i) through (iv)” to correct inadvertent cross-reference errors. 60.5415c(d)(3) Replace “§ 60.5420c(c)(14),” with “§ 60.5420c(c)(7), (9), (11), and (14),” to correct inadvertent cross-reference omissions. 60.5415c(e) introductory text Replace “from either paragraph (a), (b), (c)(2), (d)(1), (f), (g)(2)(iv), (h) or (i) of this section” with “from paragraphs (a), (b), (c)(2), (d)(1), (f)(2), (g)(2), (h)(5)(ii)(B), or (i)(12) of this section” to correct inadvertent cross-reference errors. 60.5415c(e)(1)(ix)(D)( 1) First sentence: Replace “§ 60.5387c(a)” with “§ 60.5387c” to correct an inadvertent cross-reference error. 60.5415c(e)(1)(ix)(D)( 2) First sentence: Replace “§ 60.5387c(a)” with “§ 60.5387c” to correct an inadvertent cross-reference error. 60.5415c(f) introductory text Revised to correct inadvertent cross-reference errors/omissions. 60.5415c(f)(1) Replace “§ 60.5393c(b)” with “§ 60.5393c(b) or (c)” to correct an inadvertent cross-reference omission. 60.5415c(f)(6) Replace “§ 60.5420c(c)(4), (7), (9), and (11),” with “§ 60.5420c(c)(4), (7) through (9), and (11),” to correct inadvertent cross-reference omissions. 60.5415c(g)(2) Replace “paragraph (f)” with “paragraph (e)” to correct an inadvertent cross-reference error. 60.5415c(g)(4) Replace “§ 60.5420c(c)(5)” with “§ 60.5420c(c)(5), (7), (9), and (11),” to correct inadvertent cross-reference omissions. 60.5415c(h)(3) Replace “§ 60.5396c(c)(1), by complying with paragraphs (h)(6) and (7), and (h)(9) and (10) of this section” with “§ 60.5396c(c)(1) or (2), by complying with paragraphs (h)(6), (7), (9) and (10) of this section” to correct inadvertent cross-reference error/omission and to conform paragraph referencing for purposes of format consistency. 60.5415c(h)(4) Replace “§ 60.5396c(c)(1) by” with “§ 60.5396c(c)(3) and (4) by” to correct inadvertent cross-reference error/omissions. 60.5415c(h)(9) Replace “§ 60.5420c(b)(1) and (7)” with “§ 60.5420c(b)(1) and (7) and (b)(10)(i) through (iv)” to correct inadvertent cross-reference omissions. 60.5415c(i) introductory text a. First sentence after title: Replace “paragraphs (i)(1) through (4) and (11) through (16) of this section” with “paragraphs (i)(1) through (4) and (11) through (15) of this section” to correct an inadvertent cross-reference error; and b. Last sentence: Replace “paragraphs (i)(5) through (16) of this section” with “paragraphs (i)(5) through (15) of this section” to correct an inadvertent cross-reference error. 60.5415c(i)(12) Replace “paragraph (f) of this section” with “paragraph (e) of this section” to correct an inadvertent cross-reference error. 60.5415c(i)(13) Replace “§ 60.5400c(h) or § 60.5400c(i)” with “§ 60.5400c(h) or § 60.5401c(i)” to correct an inadvertent cross-reference error. 60.5415c(i)(14) Replace “§ 60.5420b(b)(10)(i)” with “§ 60.5420c(b)(10)(i)” to correct an inadvertent typographical error. 60.5415c(j)(4) Replace “§ 60.5420c(c)(15)” with “§ 60.5420c(c)(13)” to correct an inadvertent cross-reference error. 60.5416c(a) introductory text Replace “except as provided in paragraphs (b)(6) and (7) of this section” with “except as provided in paragraphs (b)(7) and (8) of this section” to correct inadvertent cross-reference errors. 60.5416c(a)(3)(iii) Replace “§ 60.5397b(g)” with “§ 60.5397c(g)” to correct an inadvertent typographical error. 60.5417c(a) Replace “§ 60.5393c(b)(1) for your pumps designated facility” with “§ 60.5395c(b)(1) for your pumps designated facility” to correct an inadvertent cross-reference error. 60.5417c(d)(8) introductory text Amend first sentence to correct inadvertent punctuation errors (commas are added after “enclosed combustion device” and after the first “of this section”). 60.5417c(d)(8)(iii) introductory text Replace “operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C)( 1),” with “operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C),” to correct an inadvertent cross-reference error. 60.5417c(d)(8)(iii)(B) Replace “60.5415c(e)(1)(vii)(B) or (C)( 1), or paragraph (d)(8)(iii) of this section” with “60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii)” to correct an inadvertent cross-reference error. 60.5417c(d)(8)(iii)(C) Replace “§ 60.5415c(e)(1)(vii)(B) or (C)(1), or paragraph (d)(8)(iii) of this section” with “§ 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii)” to correct an inadvertent cross-reference error. 60.5417c(d)(8)(iii)(E) Replace “applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C)(1), or paragraph (d)(8)(iii) of this section” with “applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii)” to correct an inadvertent cross-reference error. 60.5417c(d)(8)(iii)(G) Last sentence: Replace “operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C)(1), or paragraph (d)(8)(iii) of this section” with “operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii)” to correct an inadvertent cross-reference error. 60.5420c(a) introductory text Last sentence: Replace “paragraph (a)(4) of this section” with “paragraph (a)(3) of this section” to correct an inadvertent cross-reference error. 60.5420c(a)(3) introductory text Replace “paragraph (a)(4)(i) and (ii)” with “paragraph (a)(3)(i) and (ii)” to correct an inadvertent cross-reference error. 60.5420c(b)(3)(i)(B) introductory text Replace “in accordance with § 60.5377c(c)” with “in accordance with § 60.5391c(c).” to correct an inadvertent cross-reference error and to correct a punctuation error (added a period). 60.5420c(b)(3)(i)(B)( 1) Replace “§ 60.5377c(c)(1), (2), (3), or (4)” with “§ 60.5391c(c)(1), (2), (3), or (4)” to correct an inadvertent cross-reference error. 60.5420c(b)(3)(ii)(A) Replace “The reason in § 60.5377c(d)(1), (2), or (3) for each incident” with “The reason in § 60.5391c(d)(1), (2), or (3) for each incident” to correct an inadvertent cross-reference error. 60.5420c(b)(3)(iii)(C) Replace “in accordance with paragraph (c)(3)(ii) of this section” with “in accordance with paragraph (b)(3)(ii) of this section” to correct an inadvertent cross-reference error. 60.5420c(b)(3)(iii)(E) a. Replace “complies with the requirements of § 60.5391c(c)” with “complies with the requirements of § 60.5391c(b)” to correct an inadvertent cross-reference error; and b. In two places, replace “§ 60.5377c” with “§ 60.5391c” to correct inadvertent cross-reference errors. 60.5420c(b)(3)(v) Replace “specified in paragraph (c)(2)(iii) of this section” with “specified in paragraph (c)(2)(vi) of this section” to correct an inadvertent cross-reference error. 60.5420c(b)(4) introductory text Revised introductory text to correct an inadvertent cross-reference error and to simplify the referencing of reporting requirements that apply to all centrifugal compressors. 60.5420c(b)(5)(iv) Replace “If complying with § 60.5393c(d)” with “If complying with § 60.5393c(d)(1) or (2)” to correct an inadvertent cross-reference error. 60.5420c(b)(6)(ii)(B) Replace “§ 60.5394c(a)(1)” with “§ 60.5394c(a)(2)” to correct an inadvertent cross-reference error. 60.5420c(b)(6)(v) Replace “specified in (b)(10)(i) through (iii) of this section” with “specified in (b)(10)(i) through (iv) of this section” to correct an inadvertent cross-reference error. 60.5420c(b)(8)(i)(F) Replace “paragraph (a)(5)” with “paragraph (a)(3)” to correct an inadvertent cross-reference error. 60.5420c(b)(8)(ii)(C) Replace “§ 60.5397c(c)(1), (2), and (7), (c)(8)(i), or (d)” with “§ 60.5397c(c)(1), (2), (7), and (8) or (d)” to correct an inadvertent cross-reference error. 60.5420c(b)(9)(v)(B) Replace “§ 60.5395c(b)(1) or (3), as applicable. by” with “§ 60.5395c(b)(1) or (3), as applicable, by” to correct a typographical punctuation error (changed “.” to a “,”). 60.5420c(b)(9)(vi) Replace “paragraphs (b)(11)(i) through (iv) of this section” with “paragraphs (b)(10)(i) through (iv) of this section” to correct an inadvertent cross-reference error. 60.5420c(b)(9)(vii) Replace “paragraph (b)(11) of this section” with “paragraph (b)(10) of this section” to correct an inadvertent cross-reference error. 60.5420c(b)(10)(v)(L) In two places, replace “§ 60.5415c(e)(x)” with “§ 60.5415c(e)(1)(x)” to correct inadvertent cross-reference errors. 60.5420c(b)(10)(v)(P) Replace “paragraphs (b)(11)(v)(N) or (O) of this section” with “paragraph (b)(10)(v)(N) or (O) of this section” to correct an inadvertent cross-reference error. 60.5420c(c)(1)(i)(A) Replace “§ 60.5376c(a)(1)” with “§ 60.5390c(a)(1)” to correct an inadvertent cross-reference error. 60.5420c(c)(1)(ii)(C) Replace “best management practice plan step taken minimize emissions” with “best management practice plan step taken to minimize emissions” to correct a typographical omission of “to”. 60.5420c(c)(2)(i)(B) introductory text Replace “§ 60.5377c(c)” with “§ 60.5391c(c)” to correct an inadvertent cross-reference error. 60.5420c(c)(2)(i)(B)( 1) Replace “§ 60.5377c(c)(1), (2), (3), or (4)” with “§ 60.5391c(c)(1), (2), (3), or (4)” to correct an inadvertent cross-reference error. 60.5420c(c)(2)(ii) introductory text Replace “§ 60.5377c(d)” with “§ 60.5391c(d)” to correct an inadvertent cross-reference error. 60.5420c(c)(2)(iv) In two places, replace “§ 60.5377c” with “§ 60.5391c” to correct inadvertent cross-reference errors. 60.5420c(c)(2)(v)(B) Replace “§ 60.5392c” with “§ 60.5391c” to correct an inadvertent cross-reference error. 60.5420c(c)(3)(ii) introductory text a. First sentence: Replace “paragraphs (c)(3)(ii)(A) through (F)” with “paragraphs (c)(3)(ii)(A) through (E)” to correct an inadvertent cross-reference error; and b. Last sentence: Replace “paragraphs (c)(3)(ii)(C) through (E)” with “paragraphs (c)(3)(ii)(B) through (E)” to correct an inadvertent cross-reference error. 60.5420c(c)(3)(ii)(A) Replace “emission reduction standard in with a control device,” with “emission reduction standard in § 60.5392c(a)(3) and (4) with a control device,” to correct inadvertent cross-reference omissions. 60.5420c(c)(3)(iii)(C) Replace “paragraphs (c)(3)(iii)(C)( 1) through ( 7)” with “paragraphs (c)(3)(iii)(C)( 1) through ( 6)” to correct an inadvertent cross-reference error. 60.5420c(c)(4) introductory text Replace “paragraphs (c)(4)(i) through (vi), and (7), (9) and (11) of this section” with “paragraphs (c)(4)(i) through (x) and (c)(7) through (12) of this section” to correct inadvertent cross-reference errors/omissions. 60.5420c(c)(4)(ii) Add “, where applicable” at the end of the sentence to correct an inadvertent omission to clarify that requirements apply conditionally. 60.5420c(c)(5)(ii)(A) introductory text Replace “§ 60.5390c(a)” with “§ 60.5394c(a)” to correct an inadvertent cross-reference error. 60.5420c(c)(6)(ii) Replace “§ 60.5396c(e)” with “§ 60.5386c(e)” to correct an inadvertent cross-reference error. 60.5420c(c)(10) introductory text a. Replace “§ 60.5395c(b)(1) for your pump designated facility” with “§ 60.5395c(b)(3) for your pump designated facility” to correct an inadvertent cross-reference error; and b. Replace “§ 60.5390c(f) for well designated facility gas well liquids unloading” with “§ 60.5390c(g) for well designated facility gas well liquids unloading” to correct an inadvertent cross-reference error. 60.5420c(c)(10)(v) In two places, replace “§ 60.5415c(e)(x)” with “§ 60.5415c(e)(1)(x)” to correct inadvertent cross-referencing errors. 60.5420c(c)(14) introductory text Replace “paragraphs (c)(14)(i) through (viii) of this section” with “paragraphs (c)(14)(i) through (ix) of this section, as applicable” to correct an inadvertent cross-reference omission. 60.5420c(d) introductory text Replace “paragraphs (g)(1) and (2)” with “paragraphs (d)(1) and (2)” to correct an inadvertent cross-reference error. 60.5421c introductory text Replace “(b)(1) through (16)” with “(b)(1) through (17)” to correct an inadvertent cross-reference error. 60.5421c(b) introductory text Replace “paragraphs (b)(1) through (16)” with “paragraphs (b)(1) through (17)” to correct an inadvertent cross-reference error. 60.5424c(e)(6) Replace “§ 60.5398c(c)(1)(ii)(D)” with “§ 60.5398c(c)(1)(iv)(D)” to correct an inadvertent cross-reference error. 60.5430c, “ Initial calibration value” definition Replace “§ 60.5403c” with “§ 60.5406c” to correct an inadvertent cross-reference error. 60.5430c, “ Repaired” definition Subparagraph (2) of definition: a. Replace “60.5400c(b) and (b)(1)” with “60.5400c(b) introductory text” to correct an inadvertent cross-reference error; and b. Replace “§ 60.5403c” with “§ 60.5406c” to correct an inadvertent cross-reference error. 60.5430c, “ Storage vessel” definition Subparagraph (1) of definition, second sentence: Replace “§ 60.5420b(c)(4)(iv)” with “§ 60.5420b(c)(6)(v)” to correct an inadvertent cross-reference error. Table 1 to Subpart OOOOc, Designated Facility Entries Replace “Process Controller”, “Pump” and “Super Emitter Emissions Events” with “Process Controllers”, “Pumps” and “Super Emitter Events” to correct typographical errors. Table 1 to Subpart OOOOc, Model Rule Presumptive Standards Section Entry for “Process Unit Equipment” Replace entry “c. Process unit equipment requirement exceptions—§ 60.5401c” with “c. Process unit equipment requirement exceptions—§ 60.5402c” to correct an inadvertent cross-reference error. 2. Clarifying Technical Corrections
This action also makes technical corrections to clarify language in the regulatory text of EG OOOOc that was erroneously included (or in some cases, erroneously omitted). Table 5 (Clarifying Technical Corrections to 40 CFR part 60, subpart OOOOc) includes the sections and paragraphs of the identified errors, the corrections being made, and the reasoning for the corrections. For the same reasons explained in Section II.C.2 discussing such corrections for NSPS OOOOb, the EPA finds good cause to make these clarifying technical corrections to the regulatory text of EG OOOOc, without prior notice and comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B).
Table 5—Clarifying Technical Corrections to 40 CFR Part 60, Subpart OOOO c
Section and paragraph Clarifying technical correction and reason for change 60.5392c(a) introductory text Revise the first to eliminate redundancy (dry seal compressor requirements included in above changes). See 89 FR 16892 to 16894 for the Final Rule preamble summary of centrifugal compressor requirements. These changes are consistent with the Final Rule preamble discussion. 60.5398c(b)(5)(ii)(A) Correcting for an inadvertent omission and to clearly state the required monitoring survey methods. See 89 FR 16874 periodic screening Final Rule preamble discussion. This correction is consistent with the Final Rule preamble discussion. 60.5398c(b)(5)(iii)(A) Replace “You must conduct a monitoring survey of all your fugitive emissions components located within a 4-meter radius of the location of the periodic screening's confirmed detection” with “You must conduct a monitoring survey of all the fugitive emissions components located within a 4-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of this part” to correct an inadvertent omission and to clearly state the required monitoring survey methods. See 89 FR 16874 periodic screening Final Rule preamble discussion. This correction is consistent with the Final Rule preamble discussion. 60.5398c(b)(5)(iv)(A) Replace “You must conduct a monitoring survey of the all the fugitive emissions components located within a 1-meter radius of the location of the periodic screening's confirmed detection” with “You must conduct a monitoring survey of all the fugitive emissions components located within a 1-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of this part” to correct an inadvertent omission and to clearly state the required monitoring survey methods. See 89 FR 16874 periodic screening Final Rule preamble discussion. This correction is consistent with the Final Rule preamble discussion. 60.5410c(c)(2) Replace “§ 60.5411c(a) and (c)” with “§ 60.5411c(a) and (c) and is routed to a control device or process” to correct an inadvertent omission to clarify that emissions are routed to a control device or process. This change is also consistent with paragraph (a)(5) of § 60.5392c of the Final Rule. See 89 FR 17150 for regulatory text. 60.5410c(d)(2) Replace “rod packing emissions collection system as required” with “rod packing emissions collection system to a process as required” to correct an inadvertent omission to clarify that emissions from the rod packing emissions collection system are routed to a process. This change is also consistent with paragraph (d)(1) of § 60.5393c of the Final Rule. See 89 FR 17151 for regulatory text. 60.5410c(f) introductory text Replace “you must perform the applicable compliance demonstrations” with “you must also perform the applicable compliance demonstrations” to correct an inadvertent omission to emphasize that performing applicable compliance demonstrations is “also” required when there is a change in compliance methods. This change does not change the requirements but adds emphasis that this is an additional requirement when changing compliance methods. 60.5410c(g) introductory text Second sentence: Replace “meet the exemption” with “meet and comply with the exemption” to correct an inadvertent omission. This change does not change requirements and is consistent with the phrasing “meet and comply with the exception” in the same sentence of this paragraph. See 89 FR 17172 for regulatory text. 60.5410c(g)(14) Replace “§ 60.5422c and the annual reports in § 60.5420c(b)(10)(i) through (iv), as applicable” with “§ 60.5422c” to reduce redundancy. The reporting requirements included in § 60.5420c(b)(10) are already cited in paragraph (b)(11)(vi) of § 60.5420c. See 89 FR 17172 for regulatory text. 60.5415c(c) introductory text Second sentence: Replace “for each wet seal and dry seal centrifugal compressor designated facility complying with § 60.5392c(a)(3) and (a)(4) or” with “for each centrifugal compressor designated facility complying with § 60.5392c(a)(3) and either (a)(4) or” to correct an inadvertent technical error. See 89 FR 16892 to 16894 for a Final Rule preamble discussion of centrifugal compressor requirements. These changes are consistent with the Final Rule preamble discussion. Paragraph (a)(4) specifies requirements when routing emissions to a control device is used to meet the standard, and paragraph (a)(5) specifies requirements when routing emissions to a process is used to meet the standard. See 89 FR 17150 for relevant § 60.5392 regulatory text. 60.5417c introductory text Replace “reciprocating compressor, process controller, storage vessel,” with “reciprocating compressor, process controller, pump, storage vessel,” to correct an inadvertent omission. This change corrects the inadvertent omission of the listing of “pump” designated facilities. Pump designated facilities, as with the other listed designated facilities are also required to demonstrate continuous compliance for each control device used to meet emission standards. See 89 FR 16883 to 16885 of the Final Rule preamble for the preamble discussion of the Final Rule requirements for pumps, which includes an option to route emissions to a control device. 60.5420c(b)(10) introductory text Last sentence: Replace “For each centrifugal compressor and storage vessel” with “For each centrifugal compressor, reciprocating compressor, and storage vessel” to correct an inadvertent omission to clarify that requirements also apply to reciprocating compressors equipped with a cover. This change is consistent with § 60.5411c introductory text and paragraph (b) of § 60.5411c of the Final Rule. See 89 FR 17173 for the Final Rule § 60.5411c regulatory text. See also, the Final Rule preamble discussion on the requirements for reciprocating compressors when routing emissions from the rod packing to a process or to a control device that reduces emissions by 95 percent at 89 FR 16896. Table 4 to Subpart OOOOc of Part 60—Applicability of General Provisions to Subpart OOOOc; General provisions citation § 60.8 Amend second sentence of “Explanation” column by replacing “Performance testing is required for control devices used on storage vessels, centrifugal compressors, and pumps, except that performance testing is not required for a control device used solely on pump(s).” with “Performance testing is required for control devices used on wells, storage vessels, centrifugal compressors, reciprocating compressors, process controllers, and pumps, as applicable, except that performance testing is not required for a control device used solely on pump(s).” These changes correct the inadvertent omission of the listing of some designated facilities where the Final Rule includes control device performance testing requirements to comply and to clarify that the performance test requirements apply conditionally ( i.e., performance test requirements would not apply where a designated facility complies with the Final Rule by meeting a compliance option that does not require control device performance testing). The EPA finds good cause to make these technical corrections and clarifications to NSPS OOOOc, identified above in Tables 4 and 5, without prior notice or comment, as these procedures are unnecessary, in accordance with APA section 553(b)(B).
A red line and strike-out version of the corrected regulatory language for NSPS OOOOc is available in Docket ID No. EPA-HQ-OAR-2021-0317.
III. Summary of Cost, Environmental, and Economic Impacts
The technical corrections included in this action do not alter the substantive requirements of the final rule, and will therefore have no cost, environmental, energy, or economic impacts beyond those already presented in the March 8, 2024, Standards of Performance for New, Reconstructed, and Modified Sources and Emissions Guidelines for Existing Sources: Oil and Natural Gas Sector Climate Review final rule (89 FR 16820) and the accompanying Regulatory Impact Analysis.
IV. Rulemaking Procedures
As noted in section I.C., the EPA's authority for the rulemaking procedures followed in this action is provided by APA section 553.[6] In general, an agency issuing a rule under the procedures in APA section 553 must provide prior notice and an opportunity for public comment, but APA section 553(b)(B) includes an exemption from notice-and-comment requirements “when the Agency for good cause finds (and incorporates the finding and a brief statement of reasons, therefore, in the rule issued) that notice and public procedure thereon are impracticable, unnecessary, or contrary to the public interest.” The EPA has determined that there is good cause to forego prior notice-and-comment procedures here because such procedures are unnecessary. The EPA is making only minor, non-substantive technical corrections and clarifications in this action; providing the public with prior notice and the opportunity for comment is unnecessary because these corrections do not change any substantive requirement of the final rule.
This action is effective immediately upon publication. Section 553(d)(3) of the APA requires publication of a final rule to precede the effective date by at least 30 days unless, as relevant here, the Agency finds good cause to make the rule effective sooner. The Agency finds that there is good cause to make the rule effective immediately upon publication under APA section 553(d)(3). See Omnipoint Corp. v. Fed. Commc'n Comm'n, 78 F.3d 620, 630 (D.C. Cir. 1996) (in determining whether good cause exists to make a rule immediately effective, an agency should “balance the necessity for immediate implementation against principles of fundamental fairness which require that all affected persons be afforded a reasonable amount of time to prepare for the effective date of its ruling”). This action addresses erroneous language (and in some cases, erroneous omissions) in the regulatory text of the final rule which, if not corrected, will lead to compliance difficulties and confusion among the regulated community about how to comply with the final rule. As the final rule is already in effect, it is critical to ensure that the regulated community and the public can rely on regulatory text that is accurate and complete. Moreover, because this action does not impose any new requirements, the regulated community does not need time to prepare for this interim final rule to come into effect.
V. Request for Comment
As explained in section IV of this document, the EPA finds good cause to issue this interim final rule without prior notice or opportunity for public comment. However, the EPA is providing an opportunity for the public to comment on the content of the technical corrections to the regulatory text being made by this action and, thus, requests comment on the revisions described herein. The EPA is not reopening for comment any provisions of the March 2024 final rule other than the specific corrections made in this interim final rule.
VI. Statutory and Executive Order Reviews
Additional information about these statutes and Executive Orders can be found at http://www.epa.gov/laws-regulations/laws-and-executive-orders.
A. Executive Order 12866: Regulatory Planning and Review, as Amended by Executive Order 14094: Modernizing Regulatory Review
This action is not a significant regulatory action as defined in Executive Order 12866, as amended by Executive Order 14094, and was therefore not subject to a requirement for Executive Order 12866 review.
B. Paperwork Reduction Act (PRA)
This action does not impose any new information collection burden under the PRA. The information collection activities for NSPS OOOOa, NSPS OOOOb, EG OOOOc have been submitted for approval to the Office of Management and Budget (OMB) under the PRA. The ICR document that the EPA prepared has been assigned OMB Control No. 2060-0721 and EPA ICR number 2523.07. The final rule ICR has been submitted to OMB as of May 1, 2024, and is awaiting approval. You can find a copy of the previously submitted ICR in EPA-HQ-OAR-2021-0317.
This action does not change the information collection requirements.
C. Regulatory Flexibility Act (RFA)
This action is not subject to the RFA. The RFA applies only to rules subject to notice and comment rulemaking requirements under the Administrative Procedure Act (APA), 5 U.S.C. 553, or any other statute. This rule is not subject to notice and comment requirements because the Agency has invoked the APA “good cause” exemption under 5 U.S.C. 553(b).
D. Unfunded Mandates Reform Act of 1995 (UMRA)
This action does not contain an unfunded mandate of $100 million or more as described in UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect small governments. The action imposes no enforceable duty on any state, local or tribal governments or the private sector. This action corrects unintended errors in the March 2024 final rule.
E. Executive Order 13132: Federalism
This action does not have federalism implications. It will not have substantial direct effects on the states, on the relationship between the national government and the states, or on the distribution of power and responsibilities among the various levels of government.
F. Executive Order 13175: Consultation and Coordination With Indian Tribal Governments
This action does not have Tribal implications as specified in Executive Order 13175. This action will implement corrections and clarifications to regulatory text applicable directly to the regulated industry that needed clarification or that were erroneously included in the final rule. Thus, Executive Order 13175 does not apply to this action.
G. Executive Order 13045: Protection of Children From Environmental Health Risks and Safety Risks
Executive Order 13045 directs federal agencies to include an evaluation of the health and safety effects of the planned regulation on children in Federal health and safety standards and explain why the regulation is preferable to potentially effective and reasonably feasible alternatives. This action is not subject to Executive Order 13045 because it is not a significant regulatory action under section 3(f)(1) of Executive Order 12866, and because the EPA does not believe the environmental health or safety risks addressed by this action present a disproportionate risk to children. The EPA does not believe there are disproportionate risks to children because of this action since it will not result in any changes to the control of air pollutants.
H. Executive Order 13211: Actions Concerning Regulations That Significantly Affect Energy Supply, Distribution, or Use
This action is not subject to Executive Order 13211 because it is not a significant regulatory action under Executive Order 12866.
I. National Technology Transfer and Advancement Act (NTTAA) and 1 CFR Part 51
This action does not involve technical standards; therefore, the NTTAA does not apply.
J. Executive Order 12898: Federal Actions To Address Environmental Justice in Minority Populations and Low-Income Populations and Executive Order 14096: Revitalizing our Nation's Commitment to Environmental Justice for All
The EPA believes that this action does not concern human health or environmental conditions and, therefore, cannot be evaluated with respect to potentially disproportionate and adverse effects on communities with environmental justice concerns.
K. Congressional Review Act (CRA)
This action is subject to the CRA, 5 U.S.C. 801-808, and the EPA will submit a rule report to each House of the Congress and to the Comptroller General of the United States. The CRA allows the issuing agency to make a rule effective sooner than otherwise provided by the CRA if the agency makes a good cause finding that notice and comment rulemaking procedures are impracticable, unnecessary, or contrary to the public interest (5 U.S.C. 808(2)). The EPA has made a good cause finding for this action as discussed in section IV of this document, including the basis for that finding.
List of Subjects in 40 CFR Part 60
- Environmental protection
- Administrative practices and procedures
- Air pollution control
- Intergovernmental relations
- Reporting and recordkeeping requirements
Michael S. Regan,
Administrator.
For the reasons set forth in the preamble, the EPA corrects 40 CFR part 60 as follows:
PART 60—STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES
1. The authority citation for part 60 continues to read as follows:
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 and on or Before December 6, 2022
2. Amend § 60.5430a by revising the definition for “ Equipment ” to read as follows:
What definitions apply to this subpart?* * * * *Equipment, as used in the standards and requirements in this subpart relative to the equipment leaks of GHG (in the form of methane) and VOC from onshore natural gas processing plants, means each pump, pressure relief device, open-ended valve or line, valve, and flange or other connector that is in VOC service or in wet gas service, and any device or system required by those same standards and requirements in this subpart.
* * * * *3. Revise table 1 to subpart OOOOa to read as follows:
Table 1 to Subpart OOOO a of Part 60—Required Minimum Initial SO 2 Emission Reduction Efficiency (Z i )
H 2 S content of acid gas (Y), (%) Sulfur feed rate (X), LT/D 2.0 ≤ X ≤ 5.0 5.0 < X ≤ 15.0 15.0 < X ≤ 300.0 X > 300.0 Y ≥ 50 79.0 88.51X0.0101 Y0.0125 or 99.9, whichever is smaller. 20 ≤ Y < 50 79.0 88.51X0.0101 Y0.0125 or 97.9, whichever is smaller 97.9 10 ≤ Y < 20 79.0 88.51X0.0101 Y0.0125 or 93.5, whichever is smaller 93.5 93.5 Y < 10 79.0 79.0 79.0 79.0 4. Revise table 2 to subpart OOOOa to read as follows:
Table 2 to Subpart OOOO a of Part 60—Required Minimum SO 2 Emission Reduction Efficiency (Z c )
H 2 S content of acid gas (Y), (%) Sulfur feed rate (X), LT/D 2.0 ≤ X ≤ 5.0 5.0 < X ≤ 15.0 15.0 < X ≤ 300.0 X > 300.0 Y ≥ 50 74.0 85.35X0.0144 Y0.0128 or 99.9, whichever is smaller. 20 ≤ Y < 50 74.0 85.35X0.0144 Y0.0128 or 97.5, whichever is smaller 97.5 10 ≤ Y < 20 74.0 85.35X0.0144 Y0.0128 or 90.8, whichever is smaller 90.8 90.8 Y < 10 74.0 74.0 74.0 74.0 * * * * *Subpart OOOOb—Standards of Performance for Crude Oil and Natural Gas Facilities for Which Construction, Modification or Reconstruction Commenced After December 6, 2022
5. Amend § 60.5365b by revising and republishing paragraphs (e), (g), (h), and (i) to read as follows:
Am I subject to this subpart?* * * * *(e) Each storage vessel affected facility, which is a tank battery that has the potential for emissions as specified in either paragraph (e)(1)(i) or (ii) of this section. A tank battery with the potential for emissions below both of the thresholds specified in paragraphs (e)(1)(i) and (ii) of this section is not a storage vessel affected facility provided the owner/operator keeps records of the potential for emissions calculation for the life of the storage vessel or until such time the tank battery becomes a storage vessel affected facility because the potential for emissions meets or exceeds either threshold specified in either paragraph (e)(1)(i) or (ii) of this section.
(1)(i) Potential for VOC emissions equal to or greater than 6 tons per year (tpy) as determined in paragraph (e)(2) of this section.
(ii) Potential for methane emissions equal to or greater than 20 tpy as determined in paragraph (e)(2) of this section.
(2) The potential for VOC and methane emissions must be calculated as the cumulative emissions from all storage vessels within the tank battery as specified by the applicable requirements in paragraphs (e)(2)(i) through (iii) of this section. The determination may take into account requirements under a legally and practicably enforceable limit in an operating permit or other requirement established under a Federal, state, local, or Tribal authority.
(i) For purposes of determining the applicability of a storage vessel tank battery as an affected facility, a legally and practicably enforceable limit must include the elements provided in paragraphs (e)(2)(i)(A) through (F) of this section.
(A) A quantitative production limit and quantitative operational limit(s) for the equipment, or quantitative operational limits for the equipment;
(B) An averaging time period for the production limit in (e)(2)(i)(A) of this section, if a production-based limit is used, that is equal to or less than 30 days;
(C) Established parametric limits for the production and/or operational limit(s) in paragraph (e)(2)(i)(A) of this section, and where a control device is used to achieve an operational limit, an initial compliance demonstration ( i.e., performance test) for the control device that establishes the parametric limits;
(D) Ongoing monitoring of the parametric limits in (e)(2)(i)(C) of this section that demonstrates continuous compliance with the production and/or operational limit(s) in (e)(2)(i)(A) of this section;
(E) Recordkeeping by the owner or operator that demonstrates continuous compliance with the limit(s) in (e)(2)(i)(A) through (D) of this section; and
(F) Periodic reporting that demonstrates continuous compliance.
(ii) For each tank battery located at a well site or centralized production facility, you must determine the potential for VOC and methane emissions within 30 days after startup of production, or within 30 days after an action specified in paragraphs (e)(3)(i) and (ii) of this section, except as provided in paragraph (e)(5)(iv) of this section. The potential for VOC and methane emissions must be calculated using a generally accepted model or calculation methodology that accounts for flashing, working, and breathing losses, based on the maximum average daily throughput to the tank battery determined for a 30-day period of production.
(iii) For each tank battery not located at a well site or centralized production facility, including each tank battery located at a compressor station or onshore natural gas processing plant, you must determine the potential for VOC and methane emissions prior to startup of the compressor station, onshore natural gas processing plant, or other facility within 30 days after an action specified in paragraphs (e)(3)(i) and (ii) of this section, using either method described in paragraph (e)(2)(iii)(A) or (B) of this section.
(A) Determine the potential for VOC and methane emissions using a generally accepted model or calculation methodology that accounts for flashing, working and breathing losses and based on the throughput to the tank battery established in a legally and practicably enforceable limit in an operating permit or other requirement established under a Federal, state, local, or Tribal authority; or
(B) Determine the potential for VOC and methane emissions using a generally accepted model or calculation methodology that accounts for flashing, working and breathing losses and based on projected maximum average daily throughput. Maximum average daily throughput is determined using a generally accepted engineering model ( e.g., volumetric condensate rates from the tank battery based on the maximum gas throughput capacity of each producing facility) to project the maximum average daily throughput for the tank battery.
(3) For the purposes of § 60.5395b, the following definitions of “reconstruction” and “modification” apply for determining when an existing tank battery becomes a storage vessel affected facility under this subpart.
(i) “Reconstruction” of a tank battery occurs when the potential for VOC or methane emissions to meet or exceed either of the thresholds specified in paragraphs (e)(1)(i) or (ii) of this section and—
(A) At least half of the storage vessels are replaced in the existing tank battery that consists of more than one storage vessel; or
(B) The provisions of § 60.15 are met for the existing tank battery.
(ii) “Modification” of a tank battery occurs when any of the actions in paragraphs (e)(3)(ii)(A) through (D) of this section occurs and the potential for VOC or methane emissions meet or exceed either of the thresholds specified in paragraphs (e)(1)(i) or (ii) of this section.
(A) A storage vessel is added to an existing tank battery;
(B) One or more storage vessels are replaced such that the cumulative storage capacity of the existing tank battery increases;
(C) For tank batteries at well sites or centralized production facilities, an existing tank battery receives additional crude oil, condensate, intermediate hydrocarbons, or produced water throughput from actions, including but not limited to, the addition of operations or a production well, or changes to operations or a production well (including hydraulic fracturing or refracturing of the well).
(D) For tank batteries not located at a well site or centralized production facility, including each tank battery at compressor stations or onshore natural gas processing plants, an existing tank battery receives additional fluids which cumulatively exceed the throughput used in the most recent ( i.e., prior to an action in paragraphs (e)(3)(ii)(A), (B) or (D) of this section) determination of the potential for VOC or methane emissions.
(4) A storage vessel affected facility that subsequently has its potential for VOC emissions decrease to less than 6 tpy shall remain an affected facility under this subpart.
(5) For storage vessels not subject to a legally and practicably enforceable limit in an operating permit or other requirement established under Federal, state, local, or Tribal authority, any vapor from the storage vessel that is recovered and routed to a process through a vapor recovery unit designed and operated as specified in this section is not required to be included in the determination of potential for VOC or methane emissions for purposes of determining affected facility status, provided you comply with the requirements of paragraphs (e)(5)(i) through (iv) of this section.
(i) You meet the cover requirements specified in § 60.5411b(b).
(ii) You meet the closed vent system requirements specified in § 60.5411b(a)(2) through (4) and (c).
(iii) You must maintain records that document compliance with paragraphs (e)(5)(i) and (ii) of this section.
(iv) In the event of removal of apparatus that recovers and routes vapor to a process, or operation that is inconsistent with the conditions specified in paragraphs (e)(5)(i) and (ii) of this section, you must determine the storage vessel's potential for VOC emissions according to this section within 30 days of such removal or operation.
(6) The requirements of this paragraph (e)(6) apply to each storage vessel affected facility immediately upon startup, startup of production, or return to service. A storage vessel affected facility or portion of a storage vessel affected facility that is reconnected to the original source of liquids remains a storage vessel affected facility subject to the same requirements that applied before being removed from service. Any storage vessel that is used to replace a storage vessel affected facility, or portion of a storage vessel affected facility, or used to expand a storage vessel affected facility assumes the affected facility status of the storage vessel affected facility being replaced or expanded.
(7) A storage vessel with a capacity greater than 100,000 gallons used to recycle water that has been passed through two stage separation is not a storage vessel affected facility.
* * * * *(g) Each sweetening unit affected facility as defined by paragraphs (g)(1) and (2) of this section.
(1) Each sweetening unit that processes natural gas produced from either onshore or offshore wells is an affected facility; and
(2) Each sweetening unit that processes natural gas followed by a sulfur recovery unit is an affected facility.
(3) Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in § 60.5423b(e) but are not required to comply with §§ 60.5405b through 60.5407b and §§ 60.5410b(i) and 60.5415b(k).
(4) Sweetening facilities producing acid gas that is completely re-injected into oil-or-gas-bearing geologic strata or that is otherwise not released to the atmosphere are not subject to §§ 60.5405b through 60.5407b, 60.5410b(i), 60.5415b(k), and 60.5423b.
(h) Each pump affected facility, which is the collection of natural gas-driven pumps at a well site, centralized production facility, onshore natural gas processing plant, or a compressor station. Pumps that are not driven by natural gas are not included in the pump affected facility.
(1) For the purposes of § 60.5393b, in addition to the definition in § 60.14, a modification occurs when the number of natural gas-driven pumps in the affected facility is increased by one or more.
(2) For the purposes of § 60.5393b, owners and operators may choose to apply reconstruction as defined in § 60.15(b) based on the fixed capital cost of the new pumps in accordance with paragraph (h)(2)(i) of this section, or the definition of reconstruction based on the number of natural gas-driven pumps in the affected facility in accordance with paragraph (h)(2)(ii) of this section. Owners and operators may choose which definition of reconstruction to apply and whether to comply with paragraph (h)(2)(i) or (ii) of this section; they do not need to apply both. If owners and operators choose to comply with paragraph (h)(2)(ii) of this section they may demonstrate compliance with § 60.15(b)(1) by showing that more than 50 percent of the number of natural gas-driven pumps is replaced. That is, if an owner or operator meets the definition of reconstruction through the “number of pumps” criterion in paragraph (h)(2)(ii) of this section, they will have shown that the “fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility,” as required in § 60.15(b)(1). Therefore, an owner or operator may comply with the remaining provisions of § 60.15 that reference “fixed capital cost” through an initial showing that the number of natural gas-driven pumps replaced exceeds 50 percent. For purposes of paragraphs (h)(2)(i) and (ii) of this section, “commenced” means that an owner or operator has undertaken a continuous program of component replacement or that an owner or operator has entered into a contractual obligation to undertake and complete, within a reasonable time, a continuous program of natural gas-driven pump replacement.
(i) If the owner or operator applies the definition of reconstruction in § 60.15, reconstruction occurs when the fixed capital cost of the new pumps exceeds 50 percent of the fixed capital cost that would be required to replace all the natural gas-driven pumps in the affected facility. The “fixed capital cost of the new pumps” includes the fixed capital cost of all natural gas-driven pumps which are or will be replaced pursuant to all continuous programs of component replacement which are commenced within any 24-month rolling period following December 6, 2022.
(ii) If the owner or operator applies the definition of reconstruction based on the percentage of natural gas-driven pumps replaced, reconstruction occurs when greater than 50 percent of the natural gas-driven pumps in the affected facility are replaced. The percentage includes all natural gas-driven pumps which are or will be replaced pursuant to all continuous programs of component replacement which are commenced within any 24-month rolling period following December 6, 2022. If an owner or operator determines reconstruction based on the percentage of natural gas-driven pumps that are replaced, the owner or operator must comply with § 60.15(a).
(3) A natural gas-driven pump that is in operation less than 90 days per calendar year is not part of an affected facility under this subpart. For the purposes of this section, any period of operation during a calendar day counts toward the 90-calendar day threshold.
(i) Each fugitive emissions components affected facility, which is the collection of fugitive emissions components at a well site, centralized production facility, or a compressor station.
(1) For purposes of § 60.5397b and § 60.5398b, a “modification” to a well site occurs when:
(i) A new well is drilled at an existing well site;
(ii) A well at an existing well site is hydraulically fractured; or
(iii) A well at an existing well site is hydraulically refractured.
(2) For purposes of § 60.5397b and § 60.5398b, a “modification” to centralized production facility occurs when:
(i) Any of the actions in paragraphs (i)(1)(i) through (iii) of this section occurs at an existing centralized production facility;
(ii) A well sending production to an existing centralized production facility is modified, as defined in paragraphs (i)(1)(i) through (iii) of this section; or
(iii) A well site subject to the requirements of § 60.5397b or § 60.5398b removes all major production and processing equipment, such that it becomes a wellhead only well site and sends production to an existing centralized production facility.
(3) For purposes of §§ 60.5397b and 60.5398b, a “modification” to a compressor station occurs when:
(i) An additional compressor is installed at a compressor station; or
(ii) One or more compressors at a compressor station is replaced by one or more compressors of greater total horsepower than the compressor(s) being replaced. When one or more compressors is replaced by one or more compressors of an equal or smaller total horsepower than the compressor(s) being replaced, installation of the replacement compressor(s) does not trigger a modification of the compressor station for purposes of §§ 60.5397b and 60.5398b.
6. Amend § 60.5370b by revising paragraph (a)(1) introductory text, (a)(1)(i), (a)(4), and (a)(7)(i) to read as follows:
When must I comply with this subpart?(a) * * *
(1) You must comply with the requirements of § 60.5385b for your reciprocating compressor affected facility as specified in paragraph (a)(1)(i), (ii), or (iii) of this section, as applicable.
(i) You must comply with the requirements of § 60.5385b(a)(1) on or before 8,760 hours of operation after May 7, 2024, on or before 8,760 hours of operation after last rod packing replacement, or on or before 8,760 hours of operation after startup, whichever date is later; and
* * * * *(4) You must comply with the requirements of § 60.5400b or as an alternative, the requirements in § 60.5401b, for all process unit equipment affected facilities at a natural gas processing plant, as soon as practicable but no later than 180 days after the initial startup of the process unit.
* * * * *(7) * * *
(i) You must comply with the requirements of § 60.5380b(a)(1) and (2) or (a)(3) for your centrifugal compressor upon initial startup.
* * * * *7. Amend § 60.5371b by revising and republishing paragraphs (c)(4), (d)(2) introductory text, and (e)(1)(v) to read as follows:
What GHG and VOC standards apply to super-emitter events?* * * * *(c) * * *
(4) Owner(s) or operator(s) of any oil and natural gas facility ( e.g., individual well site, centralized production facility, natural gas processing plant, or compressor station) within 50 meters of the latitude and longitude coordinates of the super-emitter event, if available.
* * * * *(d) * * *
(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 paragraphs (d)(2)(i) through (v) of this section.
* * * * *(e) * * *
(1) * * *
(v) 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 paragraphs (d)(2)(i) through (v) of this section 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 paragraphs (e)(1)(vi) through (viii) of this section.
* * * * *8. Amend § 60.5376b by:
a. Revising and republishing paragraphs (a)(1) introductory text;
b. Redesignating paragraphs (a)(1)(A) and (B) as paragraphs (a)(1)(i) and (ii); and
c. Revising paragraph (g)(4).
The revisions read as follows:
What GHG and VOC standards apply to gas well liquids unloading operations at well affected facilities?(a) * * *
(1) If a gas well liquids unloading operation technology or technique employed does not result in venting of methane and VOC emissions to the atmosphere, you must comply with the requirements specified in paragraphs (a)(1)(i) and (ii) and (d) and (e) of this section. If an unplanned venting event occurs, you must meet the requirements specified in paragraphs (c) through (f) of this section.
* * * * *(g) * * *
(4) You must demonstrate continuous compliance with standards that apply to well affected facility gas well liquids unloading as required by § 60.5415b(b).
* * * * *9. Amend § 60.5377b by revising paragraph (g)(2) to read as follows:
What GHG and VOC standards apply to associated gas wells at well affected facilities?* * * * *(g) * * *
(2) This demonstration must be certified by a professional engineer or another qualified individual with expertise in the uses of associated gas. The following certification, signed and dated by the qualified professional engineer or other qualified individual shall state: “I certify that the assessment of technical and safety infeasibility was prepared under my direction or supervision. I further certify that the assessment was conducted, and this report was prepared pursuant to the requirements of § 60.5377b(b). Based on my professional knowledge and experience, and inquiry of personnel involved in the assessment, the certification submitted herein is true, accurate, and complete.”
* * * * *10. Amend § 60.5380b by revising paragraph (a)(5) introductory text to read as follows:
What GHG and VOC standards apply to centrifugal compressor affected facilities?* * * * *(a) * * *
(5) If you own or operate a centrifugal compressor on the Alaska North Slope equipped with sour seal oil separator and capture system, you may comply with the GHG and VOC requirements specified in paragraphs (a)(5)(i) through (iii) of this section using volumetric flow rate as a surrogate, in lieu of meeting the requirements specified in paragraphs (a)(1) and (2) of this section. You must determine the volumetric flow rate in accordance with paragraph (a)(7)(ii) of this section.
* * * * *11. Amend § 60.5385b by revising and republishing paragraphs (a)(3) introductory text, (d)(3), and (g) to read as follows:
What GHG and VOC standards apply to reciprocating compressor affected facilities?* * * * *(a) * * *
(3) The rod packing must be repaired or replaced within 90 calendar days after the date of the volumetric emissions measurement that exceeded 2 scfm per cylinder. You must conduct follow-up volumetric flow rate measurements from compressor vents using the methods specified in paragraph (b) or (c) of this section within 15 days after the repair (or rod packing replacement) to document that the rate has been reduced to less than 2 scfm per cylinder. Delay of repair will be allowed if the conditions in paragraph (a)(3)(i) or (ii) of this section are met.
* * * * *(d) * * *
(3) As an alternative to conducting the required volumetric flow rate measurements under paragraph (a) of this section, an owner or operator can choose to comply by replacing the rod packing on or before 8,760 hours of operation after startup, on or before 8,760 hours of operation after May 7, 2024, on or before 8,760 hours of operation after the previous flow rate measurement, or on or before 8,760 hours of operation after the date of the most recent compressor rod packing replacement, whichever date is later.
* * * * *(g) You must perform the reporting requirements as specified in § 60.5420b(b)(1), (6), and (11) through (13), as applicable; and the recordkeeping requirements as specified in § 60.5420b(c)(5) and (8) through (13), as applicable.
12. Amend § 60.5386b by revising paragraphs (a)(1) introductory text and (c) introductory text to read as follows:
What test methods and procedures must I use for my centrifugal compressor and reciprocating compressor affected facilities?* * * * *(a) * * *
(1) OGI instrument. Use an OGI instrument for equipment leak detection as specified in either paragraph (a)(1)(i) or (ii) of this section. For the purposes of paragraphs (a)(1)(i) and (ii) of this section, any visible emissions observed by the OGI instrument from reciprocating rod packing or compressor dry or wet seal vent is a leak.
* * * * *(c) You must use a high-volume sampler to measure emissions of the reciprocating compressor rod packing, applicable centrifugal compressor wet seal vent, or centrifugal compressor dry seal vent in accordance with paragraphs (c)(1) through (7) of this section.
* * * * *13. Amend § 60.5393b by revising paragraphs (b)(6)(ii) and (b)(7)(iii) to read as follows:
What GHG and VOC standards apply to pump affected facilities?* * * * *(b) * * *
(6) * * *
(ii) You must maintain the records in § 60.5420b(c)(15)(ii) through (iv), as applicable. You are no longer required to maintain the records in § 60.5420b(c)(15)(v) certifying that there is no vapor recovery unit or control device on site.
(7) * * *
(iii) The following certification, signed and dated by the qualified professional engineer or in-house engineer, must state: “I certify that the assessment of technical infeasibility was prepared under my direction or supervision. I further certify that the assessment was conducted and this report was prepared pursuant to the requirements of § 60.5393b(b)(7)(ii). Based on my professional knowledge and experience, and inquiry of personnel involved in the assessment, the certification submitted herein is true, accurate, and complete.”
* * * * *14. Amend § 60.5395b by revising paragraphs (c)(1)(ii), (c)(2)(iii), and (c)(4) to read as follows:
What GHG and VOC standards apply to storage vessel affected facilities?* * * * *(c) * * *
(1) * * *
(ii) You must submit a notification as required in § 60.5420b(b)(8)(vii) in your next annual report, identifying each storage vessel affected facility removed from service during the reporting period and the date of its removal from service.
(2) * * *
(iii) You must submit a notification as required in § 60.5420b(b)(8)(vii) in your next annual report, identifying each storage vessel removed from service during the reporting period, the impacted storage vessel affected facility, and the date of its removal from service.
* * * * *(4) For each storage vessel affected facility or portion of a storage vessel affected facility returned to service during the reporting period, you must submit a notification in your next annual report as required in § 60.5420b(b)(8)(viii), identifying each storage vessel affected facility or portion of a storage vessel affected facility and the date of its return to service.
* * * * *15. Amend § 60.5397b by revising paragraphs (d) introductory text and (k) to read as follows:
What GHG and VOC standards apply to fugitive emissions components affected facilities?* * * * *(d) Additional elements of fugitive emissions monitoring plan. Each fugitive emissions monitoring plan must include the elements specified in paragraphs (d)(1) and (2) of this section, at a minimum, as applicable.
* * * * *(k) Reporting and recordkeeping. You must comply with the reporting requirements as specified in § 60.5420b(b)(1) and (9), and the recordkeeping requirements as specified in § 60.5420b(c)(14).
* * * * *16. Amend § 60.5398b by revising paragraphs (b)(5)(ii)(A), (b)(5)(iii)(A), (b)(5)(iv)(A), (d)(3)(iii)(A), and (d)(3)(vi) introductory text to read as follows:
What alternative GHG and VOC standards apply to fugitive emissions components affected facilities and what inspection and monitoring requirements apply to covers and closed vent systems when using an alternative technology?* * * * *(b) * * *
(5) * * *
(ii) * * *
(A) You must conduct a monitoring survey of all the fugitive emissions components in an affected facility using either OGI or EPA Method 21 to appendix A-7 of this part. You must follow the procedures in your monitoring plan when conducting the survey.
* * * * *(iii) * * *
(A) You must conduct a monitoring survey of all your fugitive emissions components located within a 4-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of this part. You must follow the procedures in your monitoring plan when conducting the survey.
* * * * *(iv) * * *
(A) You must conduct a monitoring survey of all the fugitive emissions components located within a 1-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of this part. You must follow the procedures in your monitoring plan when conducting the survey.
* * * * *(d) * * *
(3) * * *
(iii) * * *
(A) Description of scientific theory and appropriate references outlining the underlying technology ( e.g., reference material, literature review).
* * * * *(vi) Supporting information verifying that the technology meets the aggregate detection threshold(s) defined in paragraphs (b) and/or (c) of this section or in § 60.5371b, including supporting data to demonstrate the aggregate detection threshold of the measurement technology as applied in the field and if applicable, how probability of detection is determined. For the purpose of this subpart the average aggregate detection threshold is the average of all site-level detection thresholds from a single deployment ( e.g., a singular flight that surveys multiple well sites, centralized production facility, and/or compressor stations) of a technology, unless this technology is to be applied to § 60.5371b. When the technology is applied to § 60.5371b, then the aggregate detection threshold is the average of all site-level detection thresholds from a single deployment in the same basin and field. At a minimum, you must provide the information identified in paragraphs (d)(3)(vi)(A) through (D) of this section.
* * * * *17. Amend § 60.5400b by revising paragraphs (c)(1), (k), and (l) to read as follows:
What GHG and VOC standards apply to process unit equipment affected facilities?* * * * *(c) * * *
(1) Monitor the pump within 5 calendar days using OGI in accordance with Appendix K or the methods specified in § 60.5403b. A leak is detected if any emissions are observed using OGI or if an instrument reading of 2,000 ppmv or greater is provided using Method 21 of appendix A-7 to this part.
* * * * *(k) Reporting. You must perform the reporting requirements as specified in § 60.5420b(b)(1) and (11) through (13), as applicable, and § 60.5422b.
(l) Recordkeeping. You must perform the recordkeeping requirements as specified in § 60.5420b(c)(8) and (10) through (13), as applicable, and § 60.5421b.
18. Amend § 60.5401b by revising and republishing paragraphs (b), (c), (f), (h), (i), (l), and (m) to read as follows:
What are the alternative GHG and VOC standards for process unit equipment affected facilities?* * * * *(b) Pumps in light liquid service. You must monitor each pump in light liquid service monthly to detect leaks by the methods specified in § 60.5403b, except as provided in paragraphs (b)(2) through (6) of this section. A leak is defined as an instrument reading of 2,000 ppmv or greater. A pump that begins operation in light liquid service after the initial startup date for the process unit must be monitored for the first time within 30 days after the end of its startup period, except for a pump that replaces a leaking pump and except as provided in paragraphs (b)(2) through (6) of this section.
(1) In addition to the requirements in paragraph (b) of this section, you must conduct weekly visual inspections of all pumps in light liquid service for indications of liquids dripping from the pump seal. If there are indications of liquids dripping from the pump seal, you must follow the procedure specified in either paragraph (b)(1)(i) or (ii) of this section.
(i) Monitor the pump within 5 days using the methods specified in § 60.5403b. A leak is defined as an instrument reading of 2,000 ppmv or greater.
(ii) Designate the visual indications of liquids dripping as a leak, and repair the leak as specified in paragraph (i) of this section.
(2) Each pump equipped with a dual mechanical seal system that includes a barrier fluid system is exempt from the requirements in paragraph (b) of this section, provided the requirements specified in paragraphs (b)(2)(i) through (v) of this section are met.
(i) Each dual mechanical seal system meets the requirements of paragraphs (b)(2)(i)(A), (B), or (C) of this section.
(A) Operated with the barrier fluid at a pressure that is at all times greater than the pump stuffing box pressure; or
(B) Equipped with a barrier fluid degassing reservoir that is routed to a process or fuel gas system or connected by a closed vent system to a control device that complies with the requirements of paragraph (e) of this section; or
(C) Equipped with a system that purges the barrier fluid into a process stream with zero VOC emissions to the atmosphere.
(ii) The barrier fluid system is in heavy liquid service or does not have the potential to emit methane or VOC.
(iii) Each barrier fluid system is equipped with a sensor that will detect failure of the seal system, the barrier fluid system, or both.
(iv) Each pump is checked according to the requirements in paragraph (b)(1) of this section.
(v) Each sensor meets the requirements in paragraphs (b)(2)(v)(A) through (C) of this section.
(A) Each sensor as described in paragraph (b)(2)(iii) of this section is checked daily or is equipped with an audible alarm.
(B) You determine, based on design considerations and operating experience, a criterion that indicates failure of the seal system, the barrier fluid system, or both.
(C) If the sensor indicates failure of the seal system, the barrier fluid system, or both, based on the criterion established in paragraph (b)(2)(v)(B) of this section, a leak is detected.
(3) Any pump that is designated, as described in § 60.5421b(b)(12), for no detectable emissions, as indicated by an instrument reading of less than 500 ppmv above background, is exempt from the requirements of paragraphs (b) introductory text, (b)(1), and (2) of this section if the pump:
(i) Has no externally actuated shaft penetrating the pump housing;
(ii) Is demonstrated to be operating with no detectable emissions as indicated by an instrument reading of less than 500 ppmv above background as measured by the methods specified in § 60.5403b; and
(iii) Is tested for compliance with paragraph (b)(3)(ii) of this section initially upon designation, annually, and at other times requested by the Administrator.
(4) If any pump is equipped with a closed vent system capable of capturing and transporting any leakage from the seal or seals to a process, fuel gas system, or a control device that complies with the requirements of paragraph (e) of this section, it is exempt from paragraphs (b), (b)(1) through (3) of this section, and the repair requirements of paragraph (i) of this section.
(5) Any pump that is designated, as described in § 60.5421b(b)(13), as an unsafe-to-monitor pump is exempt from the inspection and monitoring requirements of paragraphs (b) introductory text, (b)(1), and (b)(2)(iv) and (v) of this section if the conditions in paragraphs (b)(5)(i) and (ii) of this section are met.
(i) You demonstrate that the pump is unsafe-to-monitor because monitoring personnel would be exposed to an immediate danger as a consequence of complying with paragraph (b) of this section; and
(ii) You have a written plan that requires monitoring of the pump as frequently as practicable during safe-to-monitor times, but not more frequently than the periodic monitoring schedule otherwise applicable, and you repair the equipment according to the procedures in paragraph (i) of this section if a leak is detected.
(6) Any pump that is located within the boundary of an unmanned plant site is exempt from the weekly visual inspection requirements in paragraph (b)(1) and (b)(2)(iv) of this section, and the daily requirements of paragraph (b)(2)(v) of this section, provided that each pump is visually inspected as often as practicable and at least monthly.
(c) Pressure relief devices in gas/vapor service. You must monitor each pressure relief device quarterly using the methods specified in § 60.5403b. A leak is defined as an instrument reading of 500 ppmv or greater above background.
(1) In addition to the requirements in paragraph (c) introductory text of this section, after each pressure release, you must monitor each pressure relief device within 5 calendar days after each pressure release to detect leaks. A leak is detected if an instrument reading of 500 ppmv or greater is provided using the methods specified in § 60.5403b(b).
(2) Any pressure relief device that is located in a nonfractionating plant that is monitored only by non-plant personnel may be monitored after a pressure release the next time the monitoring personnel are onsite or within 30 calendar days after a pressure release, whichever is sooner, instead of within 5 calendar days as specified in paragraph (c)(1) of this section.
(3) No pressure relief device described in paragraph (c)(2) of this section may be allowed to operate for more than 30 calendar days after a pressure release without monitoring.
(4) Any pressure relief device that is routed to a process or fuel gas system or equipped with a closed vent system capable of capturing and transporting leakage through the pressure relief device to a control device as described in paragraph (e) of this section is exempt from the requirements of paragraph (c) introductory text and (c)(1) of this section.
(5) Pressure relief devices equipped with a rupture disk are exempt from the requirements of paragraphs (c)(1) and (2) of this section provided you install a new rupture disk upstream of the pressure relief device as soon as practicable, but no later than 5 calendar days after each pressure release, except as provided in paragraph (i)(6) of this section.
* * * * *(f) Valves in gas/vapor and light liquid service. You must monitor each valve in gas/vapor and in light liquid service quarterly to detect leaks by the methods specified in § 60.5403b, except as provided in paragraphs (f)(3) through (5) of this section.
(1) A valve that begins operation in gas/vapor service or in light liquid service after the initial startup date for the process unit must be monitored for the first time within 90 days after the end of its startup period to ensure proper installation, except for a valve that replaces a leaking valve and except as provided in paragraphs (f)(3) through (5) of this section.
(2) An instrument reading of 500 ppmv or greater is a leak. You must repair each leaking valve according to the requirements in paragraph (i) of this section.
(3) Any valve that is designated, as described in § 60.5421b(b)(12), for no detectable emissions, as indicated by an instrument reading of less than 500 ppmv above background, is exempt from the monitoring requirements of paragraph (f) of this section if the valve:
(i) Has no externally actuating mechanism in contact with the process fluid;
(ii) Is operated with emissions less than 500 ppmv above background as determined by the methods specified in § 60.5403b; and
(iii) Is tested for compliance with paragraph (f)(3)(ii) of this section initially upon designation, annually, and at other times requested by the Administrator.
(4) Any valve that is designated, as described in § 60.5421b(b)(13), as an unsafe-to-monitor valve is exempt from the monitoring requirements of paragraph (f) of this section if the requirements in paragraphs (f)(4)(i) and (ii) of this section are met.
(i) You demonstrate that the valve is unsafe-to-monitor because monitoring personnel would be exposed to an immediate danger as a consequence of complying with paragraph (f) of this section; and
(ii) You have a written plan that requires monitoring of the valve as frequently as practicable during safe-to-monitor times, but not more frequently than the periodic monitoring schedule otherwise applicable, and you repair the equipment according to the procedures in paragraph (i) of this section if a leak is detected.
(5) Any valve that is designated, as described in § 60.5421b(b)(14), as a difficult-to-monitor valve is exempt from the monitoring requirements of paragraph (f) of this section if the requirements in paragraph (f)(5)(i) through (iii) of this section are met.
(i) You demonstrate that the valve cannot be monitored without elevating the monitoring personnel more than 2 meters above a support surface.
(ii) The process unit within which the valve is located has less than 3.0 percent of its total number of valves designated as difficult-to-monitor.
(iii) You have a written plan that requires monitoring of the at least once per calendar year.
* * * * *(h) Connectors in gas/vapor service and in light liquid service. You must initially monitor all connectors in the process unit for leaks by the later of either 12 months after the compliance date or 12 months after initial startup. If all connectors in the process unit have been monitored for leaks prior to the compliance date, no initial monitoring is required provided either no process changes have been made since the monitoring or the owner or operator can determine that the results of the monitoring, with or without adjustments, reliably demonstrate compliance despite process changes. If required to monitor because of a process change, you are required to monitor only those connectors involved in the process change.
(1) You must monitor all connectors in gas/vapor service and all connectors in light liquid service annually, except as provided in § 60.5399b, paragraph (e) of this section or paragraph (h)(2) of this section. If an instrument reading greater than or equal to 500 ppmv is measured, a leak is detected.
(2) Any connector that is designated, as described in § 60.5421b(b)(13), as an unsafe-to-monitor connector is exempt from the requirements of paragraphs (h) introductory text and (h)(1) of this section if the requirements of paragraphs (h)(2)(i) and (ii) of this section are met.
(i) You demonstrate the connector is unsafe-to-monitor because monitoring personnel would be exposed to an immediate danger as a consequence of complying with paragraphs (h) introductory text and (h)(1) of this section; and
(ii) You have a written plan that requires monitoring of the connector as frequently as practicable during safe-to-monitor times, but not more frequently than the periodic monitoring schedule otherwise applicable, and you repair the equipment according to the procedures in paragraph (i) of this section if a leak is detected.
(3) Inaccessible, ceramic, or ceramic-line connectors.
(i) Any connector that is inaccessible or that is ceramic or ceramic-lined ( e.g., porcelain, glass, or glass-lined), is exempt from the monitoring requirements of paragraphs (h) and (h)(1) of this section, from the leak repair requirements of paragraph (i) of this section, and from the recordkeeping and reporting requirements of §§ 60.5421b and 60.5422b. An inaccessible connector is one that meets any of the specifications in paragraphs (h)(3)(i)(A) through (F) of this section, as applicable.
(A) Buried.
(B) Insulated in a manner that prevents access to the connector by a monitor probe.
(C) Obstructed by equipment or piping that prevents access to the connector by a monitor probe.
(D) Unable to be reached from a wheeled scissor-lift or hydraulic-type scaffold that would allow access to connectors up to 7.6 meters (25 feet) above the ground.
(E) Inaccessible because it would require elevating monitoring personnel more than 2 meters (7 feet) above a permanent support surface or would require the erection of scaffold.
(F) Not able to be accessed at any time in a safe manner to perform monitoring. Unsafe access includes, but is not limited to, the use of a wheeled scissor-lift on unstable or uneven terrain, the use of a motorized man-lift basket in areas where an ignition potential exists, or access would require near proximity to hazards such as electrical lines or would risk damage to equipment.
(ii) If any inaccessible, ceramic, or ceramic-lined connector is observed by AVO or other means to be leaking, the indications of a leak to the atmosphere by AVO or other means must be eliminated as soon as practicable.
(4) Connectors which are part of an instrumentation systems and inaccessible, ceramic, or ceramic-lined connectors meeting the provisions of paragraph (h)(3) of this section, are not subject to the recordkeeping requirements of § 60.5421b(b)(1).
(i) Repair requirements. When a leak is detected, comply with the requirements of paragraphs (i)(1) through (5) of this section, except as provided in paragraph (i)(6) of this section.
(1) A weatherproof and readily visible identification tag, marked with the equipment identification number, must be attached to the leaking equipment. The identification tag on the equipment may be removed after it has been repaired.
(2) A first attempt at repair must be made as soon as practicable, but no later than 5 calendar days after the leak is detected.
(i) First attempts at repair for pumps in light liquid or heavy liquid service include, but are not limited to, the practices described in paragraphs (i)(2)(i)(A) and (B) of this section, where practicable.
(A) Tightening the packing gland nuts.
(B) Ensuring that the seal flush is operating at design pressure and temperature.
(ii) For each valve where a leak is detected, you must comply with paragraph (i)(2)(ii)(A), (B), or (C) of this section, unless you meet the requirements of paragraph (i)(2)(ii)(D) of this section.
(A) Repack the existing valve with a low-e packing.
(B) Replace the existing valve with a low-e valve; or
(C) Perform a drill and tap repair with a low-e injectable packing.
(D) An owner or operator is not required to utilize a low-e valve or low-e packing to replace or repack a valve if the owner or operator demonstrates that a low-e valve or low-e packing is not technically feasible. Low-e valve or low-e packing that is not suitable for its intended use is considered to be technically infeasible. Factors that may be considered in determining technical infeasibility include: retrofit requirements for installation ( e.g., re-piping or space limitation), commercial unavailability for valve type, or certain instrumentation assemblies.
(3) Repair of leaking equipment must be completed within 15 calendar days after detection of each leak, except as provided in paragraph (i)(4), (5), or (6) of this section.
(4) If the repair for visual indications of liquids dripping for pumps in light liquid service can be made by eliminating visual indications of liquids dripping, you must make the repair within 5 calendar days of detection.
(5) If the repair for AVO or other indication of a leak for open-ended lines or valves; pumps, valves, or connectors in heavy liquid service; or pressure relief devices in light liquid or heavy liquid service can be made by eliminating the AVO, or other indication of a potential leak, you must make the repair within 5 calendar days of detection.
(6) Delay of repair of equipment for which leaks have been detected will be allowed if repair within 15 calendar days is technically infeasible without a process unit shutdown or as specified in paragraphs (i)(6)(i) through (v) of this section. Repair of this equipment shall occur before the end of the next process unit shutdown. Monitoring to verify repair must occur within 15 calendar days after startup of the process unit.
(i) Delay of repair of equipment will be allowed for equipment which is isolated from the process, and which does not have the potential to emit methane or VOC.
(ii) Delay of repair for valves and connectors will be allowed if the conditions in paragraphs (i)(6)(ii)(A) and (B) are met.
(A) You demonstrate that emissions of purged material resulting from immediate repair are greater than the fugitive emissions likely to result from delay of repair, and
(B) When repair procedures are conducted, the purged material is collected and destroyed or recovered in a control device complying with paragraph (e) of this section.
(iii) Delay of repair for pumps will be allowed if the conditions in paragraphs (i)(6)(iii)(A) and (B) are met.
(A) Repair requires the use of a dual mechanical seal system that includes a barrier fluid system, and
(B) Repair is completed as soon as practicable, but not later than 6 months after the leak was detected.
(iv) If delay of repair is required to repack or replace the valve, you may use delay of repair. Delay of repair beyond a process unit shutdown will be allowed for a valve, if valve assembly replacement is necessary during the process unit shutdown, valve assembly supplies have been depleted, and valve assembly supplies had been sufficiently stocked before the supplies were depleted. Delay of repair beyond the next process unit shutdown will not be allowed unless the next process unit shutdown occurs sooner than 6 months after the first process unit shutdown.
(v) When delay of repair is allowed for a leaking pump, valve, or connector that remains in service, the pump, valve, or connector may be considered to be repaired and no longer subject to delay of repair requirements if two consecutive monthly monitoring results show no leak remains.
* * * * *(l) Reporting. You must perform the reporting requirements as specified in § 60.5420b(b)(1) and (11) through (13), as applicable, and § 60.5422b.
(m) Recordkeeping. You must perform the recordkeeping requirements as specified in § 60.5420b(c)(8) and (10) through (13), as applicable, and § 60.5421b.
19. Amend § 60.5402b by revising paragraph (d) introductory text to read as follows:
What are the exceptions to the GHG and VOC standards for process unit equipment affected facilities?* * * * *(d) You may use the following provisions instead of § 60.5403b(d):
* * * * *20. Amend § 60.5403b by revising paragraph (c) introductory text to read as follows:
What test methods and procedures must I use for my process unit equipment affected facilities?* * * * *(c) You shall determine compliance with the no detectable emission standards in § 60.5401b(b) and (f) as specified in paragraphs (c)(1) and (2) of this section.
* * * * *[Amended]21. Amend § 60.5406b by redesignating the second paragraph (c)(4)(iv) as paragraph (c)(4)(vi).
22. Amend § 60.5407b by revising paragraph (b)(4) to read as follows:
What are the requirements for monitoring of emissions and operations from my sweetening unit affected facilities?* * * * *(b) * * *
(4) Upon promulgation of a performance specification of continuous monitoring systems for total reduced sulfur compounds at sulfur recovery plants, you may, as an alternative to paragraph (b)(2) of this section, install, calibrate, maintain, and operate a continuous emission monitoring system for total reduced sulfur compounds as required in paragraph (c) of this section in addition to a sulfur dioxide emission monitoring system. The sum of the equivalent sulfur mass emission rates from the two monitoring systems must be used to compute the total sulfur emission rate (E).
* * * * *23. Amend § 60.5410b by revising and republishing paragraphs (b)(4) introductory text, (c), (d)(2) and (6), (e)(3), (f) introductory text, (f)(2) introductory text, (g), and (h)(12) to read as follows:
How do I demonstrate initial compliance with the standards for each of my affected facilities?* * * * *(b) * * *
(4) If you comply by using § 60.5376b(g), you must comply with paragraphs (b)(4)(i) through (vi) of this section.
* * * * *(c) Associated gas well standards for well affected facility. To demonstrate initial compliance with the GHG and VOC standards for each associated gas well as required by § 60.5377b, you must comply with paragraphs (c)(1) through (4) of this section.
(1) If you comply with the requirements of § 60.5377b(a), you must maintain the records specified in § 60.5420b(c)(3)(i), (ii), and (iv).
(2) For associated gas wells that comply with § 60.5377b(f) based on a demonstration and certification that it is not feasible to comply with paragraphs (a)(1), (2), (3), and (4) of this section due to technical reasons in accordance with paragraph § 60.5377b(g), you must comply with paragraphs (c)(2)(i) and (ii) of this section.
(i) Document the technical reasons why it is infeasible to route recovered associated gas into a gas gathering flow line or collection system to a sales line, use it as an onsite fuel source, use it for another useful purpose that a purchased fuel or raw material would serve, or re-inject it into the well or inject it into another well, maintain the documentation in accordance with § 60.5377(g), and submit this documentation in the initial annual report as required by paragraph (c)(4) of this section.
(ii) Maintain a copy of the certification and submit the certification as required by § 60.5377b(g).
(3) If you comply with § 60.5377b(d) or (f), you must comply with paragraphs (c)(3)(i) through (vi) of this section.
(i) Reduce methane and VOC emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413b.
(ii) Install a closed vent system that meets the requirements of § 60.5411b(a) and (c) to capture the associated gas and route the captured associated gas to a control device that meets the conditions specified in § 60.5412b.
(iii) Conduct an initial performance test as required in § 60.5413b within 180 days after initial startup or by May 7, 2024, whichever date is later, or install a control device tested under § 60.5413b(d) which meets the criteria in § 60.5413b(d)(11) and (e) and you must comply with the continuous compliance requirements of § 60.5415b(f).
(iv) Conduct the initial inspections required in § 60.5416b(a) and (b).
(v) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417b(a) through (i), as applicable.
(vi) Maintain the records specified in § 60.5420b(c)(3)(iv) and (c)(8) and (c)(10) through (13), as applicable.
(4) You must submit the initial annual report for your associated gas well as required in § 60.5420b(b)(1) and (4) and (b)(11) through (13), as applicable.
(d) * * *
(2) If you use a control device to reduce emissions to comply with § 60.5380b(a)(1) and (2), you must equip the wet seal fluid degassing system with a cover that meets the requirements of § 60.5411b(b) that is connected through a closed vent system that meets the requirements of § 60.5411b(a) and (c) and is routed to a control device that meets the conditions specified in § 60.5412b. If you comply with § 60.5380b(a)(3) by routing the closed vent system to a process as an alternative to routing the closed vent system to a control device, you must equip the wet seal fluid degassing system with a cover that meets the requirements of § 60.5411b(b), and route captured vapors through a closed vent system to a process that meets the requirements of § 60.5411b(a) and (c).
* * * * *(6) You must maintain the volumetric flow rates for your centrifugal compressors as specified in paragraphs (d)(6)(i) through (iii) of this section, as applicable.
(i) For your self-contained wet seal centrifugal compressors, you must maintain the volumetric flow rate at or below 3 scfm per seal. You must conduct your initial annual volumetric measurement as required by § 60.5380b(a)(4).
(ii) For your centrifugal compressor on the Alaska North Slope equipped with sour seal oil separator and capture system, you must maintain the volumetric flow rate at or below 9 scfm per seal. You must conduct your initial annual volumetric measurement as required by § 60.5380b(a)(5).
(iii) For your dry seal centrifugal compressor, you must maintain the volumetric flow rate at or below 10 scfm per seal. You must conduct your initial annual volumetric measurement as required by § 60.5380b(a)(6).
* * * * *(e) * * *
(3) If you comply with § 60.5385b(d) by collecting the emissions from your rod packing emissions collection system by using a control device to reduce VOC and methane emissions by 95.0 percent as required by § 60.5385b(d)(2), you must equip the reciprocating compressor with a cover that meets the requirements of § 60.5411b(b), route emissions to a control device that meets the conditions specified in § 60.5412b through a closed vent system that meets the requirements of § 60.5411b(a) and (c) and you must conduct the initial inspections required in § 60.5416b(a) and (b).
* * * * *(f) Process controller affected facility. To demonstrate initial compliance with GHG and VOC emission standards for your process controller affected facility as required by § 60.5390b, you must comply with paragraphs (f)(1) through (5) of this section, as applicable. If you change compliance methods, you must also perform the applicable compliance demonstrations of paragraphs (f)(1) through (3) of this section again for the new compliance method, note the change in compliance method in the annual report required by § 60.5420b(b)(7)(iv), and maintain the records required by paragraph (f)(5) of this section for the new compliance method.
* * * * *(2) For each process controller affected facility located at a site in Alaska that does not have access to electrical power, you must demonstrate initial compliance with § 60.5390b(b)(1) and (2) or with § 60.5390b(b)(3), instead of complying with paragraph § 60.5390b(a), by meeting the requirements specified in (f)(2)(i) through (iv) of this section for each process controller, as applicable.
* * * * *(g) Pump affected facility. To demonstrate initial compliance with the GHG and VOC standards for your pump affected facility as required by § 60.5393b, you must comply with paragraphs (g)(1) through (4) of this section, as applicable. If you change compliance methods, you must also perform the applicable compliance demonstrations of paragraphs (g)(1) and (2) of this section again for the new compliance method, note the change in compliance method in the annual report required by § 60.5420b(b)(10)(v)(C), and maintain the records required by paragraph (g)(4) of this section for the new compliance method.
(1) For pump affected facilities complying with the requirements of § 60.5393b(a) or (b)(2) by routing emissions to a process, you must meet the requirements specified in paragraphs (g)(1)(ii) and (iv) of this section. For pump affected facilities complying with the requirements of § 60.5393b(b)(3), you must meet the requirements specified in paragraphs (g)(1)(i) through (v) of this section.
(i) Reduce methane and VOC emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413b.
(ii) Install a closed vent system that meets the requirements of § 60.5411b(a) and (c) to capture all emissions from all pumps in the pump affected facility and route all emissions to a process or control device that meets the conditions specified in § 60.5412b.
(iii) Conduct an initial performance test as required in § 60.5413b within 180 days after initial startup or by May 7, 2024, whichever date is later, or install a control device tested under § 60.5413b(d) which meets the criteria in § 60.5413b(d)(11) and (e) and you must comply with the continuous compliance requirements of § 60.5415b(f).
(iv) Conduct the initial inspections of the closed vent system and bypasses, if applicable, as required in § 60.5416b(a) and (b).
(v) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417b(a) through (i), as applicable.
(2) Submit the certifications specified in paragraphs (g)(2)(i) through (iii) of this section, as applicable.
(i) The certification required by § 60.5393b(b)(5) that there is no vapor recovery unit on site and that there is a control device on site, but it does not achieve a 95.0 percent emissions reduction.
(ii) The certification required by § 60.5393b(b)(6) that there is no control device or process available on site.
(iii) The certification required by § 60.5393b(b)(7) that it is technically infeasible to capture and route the pump affected facility emissions to a process or an existing control device.
(3) You must submit the initial annual report for your pump affected facility as specified in § 60.5420b(b)(1), (10), and (b)(11) through (13), as applicable.
(4) You must maintain the records for your pump affected facility as specified in § 60.5420b(c)(8) and (c)(10) through (13), as applicable, and (c)(15).
(h) * * *
(12) You must tag and repair each identified leak as required in § 60.5400b(h) or § 60.5401b(i), as applicable.
* * * * *24. Amend § 60.5411b by revising paragraph (b)(4) to read as follows:
What additional requirements must I meet to determine initial compliance for my covers and closed vent systems?* * * * *(b) * * *
(4) You must design and operate the cover with no identifiable emissions as demonstrated by § 60.5416b(a) and (b), except when operated as provided in paragraphs (b)(2)(i) through (iv) of this section.
* * * * *25. Amend § 60.5412b by revising paragraphs (a) introductory text, (c)(1)(i), and (d)(4) to read as follows:
What additional requirements must I meet for determining initial compliance of my control devices?* * * * *(a) Each control device used to meet the emissions reduction standard in § 60.5377b(d) or (f) for your associated gas well at a well affected facility; § 60.5376b(g) for your well affected facility gas well that unloads liquids; § 60.5380b(a)(1) or (9) for your centrifugal compressor affected facility; § 60.5385b(d)(2) for your reciprocating compressor affected facility; § 60.5395b(a)(2) for your storage vessel affected facility; § 60.5390b(b)(3) for your process controller affected facility in Alaska; § 60.5393b(b)(3) for your pumps affected facility; or either § 60.5400b(f) or § 60.5401b(e) for your process equipment affected facility must be installed according to paragraphs (a)(1) through (3) of this section. As an alternative to paragraph (a)(1) of this section, you may install a combustion control device model tested under § 60.5413b(d), which meets the criteria in § 60.5413b(d)(11) and which meets the initial and continuous compliance requirements in § 60.5413b(e).
* * * * *(c) * * *
(1) * * *
(i) Following the initial startup of the control device, you must replace all carbon in the carbon adsorption system with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established according to § 60.5413b(c)(2) or (3). You must maintain records identifying the schedule for replacement and records of each carbon replacement as required in § 60.5420b(c)(11).
* * * * *(d) * * *
(4) The alternative test method must be capable of documenting periods when the enclosed combustion device or flare operates with visible emissions. If the alternative test method cannot identify periods of visible emissions, you must conduct the inspections required by § 60.5417b(d)(8)(v).
* * * * *26. Amend § 60.5413b by revising the introductory text to read as follows:
What are the performance testing procedures for control devices?This section applies to the performance testing of control devices used to demonstrate compliance with the emissions standards for your well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment affected facilities. You must demonstrate that a control device achieves the performance requirements of § 60.5412b(a)(1) or (2) using the performance test methods and procedures specified in this section. For condensers and carbon adsorbers, you may use a design analysis as specified in paragraph (c) of this section in lieu of complying with paragraph (b) of this section. In addition, this section contains the requirements for enclosed combustion device performance tests conducted by the manufacturer applicable to well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment affected facilities.
* * * * *27. Amend § 60.5415b by revising and republishing paragraphs (d), (e), (f), (h), (i), (k), and (l) to read as follows:
How do I demonstrate continuous compliance with the standards for each of my affected facilities?* * * * *(d) Centrifugal compressor affected facility. For each wet seal centrifugal compressor affected facility complying with § 60.5380b(a)(1) and (2), or with § 60.5380b(a)(3) by routing emissions to a control device or to a process, you must demonstrate continuous compliance according to paragraph (d)(1) and paragraphs (d)(3) and (4) of this section. For each self-contained wet seal centrifugal compressor complying with the requirements in § 60.5380b(a)(4), you must demonstrate continuous compliance according to paragraphs (d)(2) through (4) of this section. For each centrifugal compressor on the Alaska North Slope equipped with sour seal oil separator and capture system, complying with the requirements of § 60.5380b(a)(5), you must demonstrate continuous compliance according to paragraphs (d)(2) through (4) of this section. For each dry seal centrifugal compressor complying with the requirements in § 60.5380b(a)(6), you must demonstrate continuous compliance according to paragraphs (d)(2) through (4) of this section.
(1) For each wet seal centrifugal compressor affected facility complying by routing emissions to a control device or to a process, you must operate the wet seal emissions collection system to route emissions to a control device or a process through a closed vent system and continuously comply with the cover and closed vent requirements of § 60.5416b. If you comply with § 60.5380b(a)(2) by using a control device, you also must comply with the requirements in paragraph (f) of this section.
(2) You must maintain volumetric flow rate at or below the flow rates specified in § 60.5380b(a)(4) for you self-contained centrifugal compressor, § 60.5380b(a)(5) for your Alaska North Slope centrifugal compressor equipped with a sour seal oil separator and capture system, and § 60.5380b(a)(6) for your centrifugal compressor equipped with dry seals, as applicable. You must conduct the required volumetric flow rate measurement of your self-contained wet seal centrifugal compressor in accordance with § 60.5380b(a)(4), your Alaska North Slope centrifugal compressor equipped with a sour seal oil separator and capture system in accordance with § 60.5380b(a)(5), and your dry seal centrifugal compressor in accordance with § 60.5380b(a)(6), as applicable, on or before 8,760 hours of operation after your last volumetric flow rate measurement which demonstrates compliance with the volumetric flow rate specified in § 60.5380b(a)(4) for your self-contained centrifugal compressor, § 60.5380b(a)(5) for your Alaska North Slope centrifugal compressor equipped with a sour seal oil separator and capture system and § 60.5380b(a)(6) for your centrifugal compressor equipped with dry seals, as applicable.
(3) You must submit the annual reports as required in § 60.5420b(b)(1), (5), and (11)(i) through (iv), as applicable.
(4) You must maintain records as required in § 60.5420b(c)(4), (8) through (10), and (12), as applicable.
(e) Pump affected facility. To demonstrate continuous compliance with the GHG and VOC standards for your pump affected facility as required by § 60.5393b, you must comply with paragraphs (e)(1) through (3) of this section.
(1) For pump affected facilities complying with the requirements of § 60.5393b(a) by routing emissions to a process, and for pump affected facilities complying with the requirements of § 60.5393b(b)(2), or (3), you must route emissions through a closed vent system and continuously comply with the closed vent requirements of § 60.5416b. If you comply with § 60.5393b(b)(3), you also must comply with the requirements in paragraph (f) of this section.
(2) You must submit the annual reports for your pump affected facility as required in § 60.5420b(b)(1), (10), and (11)(i) through (iv), as applicable.
(3) You must maintain the records for your pump affected facility as specified in § 60.5420b(c)(8), (10) through (12), and (15), as applicable.
(f) Additional continuous compliance requirements for well, centrifugal compressor, reciprocating compressor, process controllers in Alaska, storage vessel, process unit equipment, or pump affected facilities. For each associated gas well, each gas well that conducts liquids unloading, each centrifugal compressor affected facility, each reciprocating compressor affected facility, each process controller affected facility in Alaska, each storage vessel affected facility, each process unit equipment affected facility, and each pump affected facility referenced to this paragraph from either paragraph (b), (c), (d)(1), (e)(1), (g)(2), (h)(2), (i)(5)(ii)(B), or (j)(12) of this section, you must also install monitoring systems as specified in § 60.5417b, demonstrate continuous compliance according to paragraph (f)(1) of this section, maintain the records in paragraph (f)(2) of this section, and comply with the reporting requirements specified in paragraph (f)(3) of this section.
(1) You must demonstrate continuous compliance with the control device performance requirements of § 60.5412b(a) using the procedures specified in paragraphs (f)(1)(i) through (viii) of this section and conducting the monitoring as required by § 60.5417b. If you use a condenser as the control device to achieve the requirements specified in § 60.5412b(a)(2), you may demonstrate compliance according to paragraph (f)(1)(ix) of this section. You may switch between compliance with paragraphs (f)(1)(i) through (viii) of this section and compliance with paragraph (f)(1)(ix) of this section only after at least 1 year of operation in compliance with the selected approach. You must provide notification of such a change in the compliance method in the next annual report, following the change. If you use an enclosed combustion device or a flare as the control device, you must also conduct the monitoring required in paragraph (f)(1)(x) of this section. If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d), you must use the procedures in paragraph (f)(1)(xi) of this section in lieu of the procedures in paragraphs (f)(1)(i) through (viii) of this section, but you must still conduct the monitoring required in paragraph (f)(1)(x) of this section.
(i) You must operate below (or above) the site-specific maximum (or minimum) parameter value established according to the requirements of § 60.5417b(f)(1). For flares, you must operate above the limits specified in paragraphs (f)(1)(vii)(B) of this section.
(ii) You must calculate the average of the applicable monitored parameter in accordance with § 60.5417b(e).
(iii) Compliance with the operating parameter limit is achieved when the average of the monitoring parameter value calculated under paragraph (f)(1)(ii) of this section is either equal to or greater than the minimum parameter value or equal to or less than the maximum parameter value established under paragraph (f)(1)(i) of this section. When performance testing of a combustion control device is conducted by the device manufacturer as specified in § 60.5413b(d), compliance with the operating parameter limit is achieved when the criteria in § 60.5413b(e) are met.
(iv) You must operate the continuous monitoring system required in § 60.5417b(a) at all times the affected source is operating, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities, including, as applicable, system accuracy audits and required zero and span adjustments. A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. You are required to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
(v) You may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report emissions or operating levels. You must use all the data collected during all other required data collection periods to assess the operation of the control device and associated control system.
(vi) Failure to collect required data is a deviation of the monitoring requirements.
(vii) If you use an enclosed combustion device to meet the requirements of § 60.5412b(a)(1) and you demonstrate compliance using the test procedures specified in § 60.5413b(b), or you use a flare designed and operated in accordance with § 60.5412b(a)(3), you must comply with the applicable requirements in paragraphs (f)(1)(vii)(A) through (E) of this section.
(A) For each enclosed combustion device which is not a catalytic vapor incinerator and for each flare, you must comply with the requirements in paragraphs (f)(1)(vii)(A)( 1) through ( 4) of this section.
( 1) A pilot or combustion flame must be present at all times of operation. An alert must be sent to the nearest control room whenever the pilot or combustion flame is unlit.
( 2) Devices must be operated with no visible emissions, except for periods not to exceed a total of 1 minute during any 15-minute period. A visible emissions test conducted according to section 11 of Method 22 of appendix A-7 to this part, must be performed at least once every calendar month, separated by at least 15 days between each test. The observation period shall be 15 minutes or once the amount of time visible emissions is present has exceeded 1 minute, whichever time period is less. Alternatively, you may conduct visible emissions monitoring according to § 60.5417b(h).
( 3) Devices failing the visible emissions test must follow manufacturer's repair instructions, if available, or best combustion engineering practice as outlined in the unit inspection and maintenance plan, to return the unit to compliant operation. All repairs and maintenance activities for each unit must be recorded in a maintenance and repair log and must be available for inspection.
( 4) Following return to operation from maintenance or repair activity, each device must pass a Method 22 of appendix A-7 to this part visual observation as described in paragraph (f)(1)(vii)(A)( 2) of this section or be monitored according to § 60.5417b(h).
(B) For flares, you must comply with the requirements in paragraphs (f)(1)(vii)(B)( 1) through ( 6) of this section.
( 1) For unassisted flares, maintain the NHV of the gas sent to the flare at or above 200 Btu/scf.
( 2) If you use a pressure assisted flare, maintain the NHV of gas sent to the flare at or above 800 Btu/scf.
( 3 ) For steam-assisted and air-assisted flares, maintain the NHVcz at or above 270 Btu/scf.
( 4 ) For flares with perimeter assist air, maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the flare is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are not required to comply with the NHVdil limit.
( 5) Unless you use a pressure-assisted flare, maintain the flare tip velocity below the applicable limits in § 60.18(b).
(6) Maintain the total gas flow to the flare above the minimum inlet gas flow rate. The minimum inlet gas flow rate is established based on manufacturer recommendations.
(C) For enclosed combustion devices for which, during the performance test conducted under § 60.5413b(b), the combustion zone temperature is not an indicator of destruction efficiency, you must comply with the requirements in paragraphs (f)(1)(vii)(C)( 1) through ( 5) of this section, as applicable.
( 1) Maintain the total gas flow to the enclosed combustion device at or above the minimum inlet gas flow rate and at or below the maximum inlet flow rate for the enclosed combustion device established in accordance with § 60.5417b(f).
( 2) For unassisted enclosed combustion devices, maintain the NHV of the gas sent to the enclosed combustion device at or above 200 Btu/scf.
( 3) For enclosed combustion devices that use pressure-assisted burner tips to promote mixing at the burner tip, maintain the NHV of the gas sent to the enclosed combustion device at or above 800 Btu/scf.
( 4 ) For steam-assisted and air-assisted enclosed combustion devices, maintain the NHVcz at or above 270 Btu/scf.
( 5 ) For enclosed combustion devices with perimeter assist air, maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the enclosed combustion device is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are not required to comply with the NHVdil limit.
(D) For enclosed combustion devices for which, during the performance test conducted under § 60.5413b(b), the combustion zone temperature is demonstrated to be an indicator of destruction efficiency, you must comply with the requirements in paragraphs (f)(1)(vii)(D)( 1) and ( 2) of this section.
( 1) Maintain the temperature at or above the minimum temperature established during the most recent performance test. The minimum temperature limit established during the most recent performance test is the average temperature recorded during each test run, averaged across the 3 test runs (average of the test run averages).
( 2) Maintain the total gas flow to the enclosed combustion device at or above the minimum inlet gas flow rate and at or below the maximum inlet flow rate for the enclosed combustion device established in accordance with § 60.5417b(f).
(E) For catalytic vapor incinerators you must operate the catalytic vapor incinerator at or above the minimum temperature of the catalyst bed inlet and at or above the minimum temperature differential between the catalyst bed inlet and the catalyst bed outlet established in accordance with § 60.5417b(f).
(viii) If you use a carbon adsorption system as the control device to meet the requirements of § 60.5412b(a)(2), you must demonstrate compliance by the procedures in paragraphs (f)(1)(viii)(A) and (B) of this section, as applicable.
(A) If you use a regenerative-type carbon adsorption system, you must comply with paragraphs (f)(1)(viii)(A)( 1) through ( 4) of this section.
( 1) You must maintain the average regenerative mass flow or volumetric flow to the carbon adsorber during each bed regeneration cycle above the limit established in in accordance with § 60.5413b(c)(2).
( 2) You must maintain the average carbon bed temperature above the temperature limit established in accordance with § 60.5413b(c)(2) during the carbon bed steaming cycle and below the carbon bed temperature established in in accordance with § 60.5413b(c)(2) after the regeneration cycle.
( 3) You must check the mechanical connections for leakage at least every month, and you must perform a visual inspection at least every 3 months of all components of the continuous parameter monitoring system for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if your continuous parameter monitoring system is not equipped with a redundant flow sensor.
( 4) You must replace all carbon in the carbon adsorption system with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established according to § 60.5413b(c)(2).
(B) If you use a nonregenerative-type carbon adsorption system, you must replace all carbon in the control device with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established according to § 60.5413b(c)(3).
(ix) If you use a condenser as the control device to achieve the percent reduction performance requirements specified in § 60.5412b(a)(2), you must demonstrate compliance using the procedures in paragraphs (f)(1)(ix)(A) through (E) of this section.
(A) You must establish a site-specific condenser performance curve according to § 60.5417b(f)(2).
(B) You must calculate the daily average condenser outlet temperature in accordance with § 60.5417b(e).
(C) You must determine the condenser efficiency for the current operating day using the daily average condenser outlet temperature calculated under paragraph (f)(1)(ix)(B) of this section and the condenser performance curve established under paragraph (f)(1)(ix)(A) of this section.
(D) Except as provided in paragraphs (f)(1)(ix)(D)( 1) and ( 2) of this section, at the end of each operating day, you must calculate the 365-day rolling average TOC emission reduction, as appropriate, from the condenser efficiencies as determined in paragraph (f)(1)(ix)(C) of this section.
( 1) After the compliance dates specified in § 60.5370b(a), if you have less than 120 days of data for determining average TOC emission reduction, you must calculate the average TOC emission reduction for the first 120 days of operation after the compliance date. You have demonstrated compliance with the overall 95.0 percent reduction requirement if the 120-day average TOC emission reduction is equal to or greater than 95.0 percent.
( 2) After 120 days and no more than 364 days of operation after the compliance date specified in § 60.5370b(a), you must calculate the average TOC emission reduction as the TOC emission reduction averaged over the number of days between the current day and the applicable compliance date. You have demonstrated compliance with the overall 95.0 percent reduction requirement if the average TOC emission reduction is equal to or greater than 95.0 percent.
(E) If you have data for 365 days or more of operation, you have demonstrated compliance with the TOC emission reduction if the rolling 365-day average TOC emission reduction calculated in paragraph (f)(1)(ix)(D) of this section is equal to or greater than 95.0 percent.
(x) During each inspection conducted using an OGI camera under § 60.5397b and during each periodic screening event or each inspection conducted using an OGI camera under § 60.5398b, you must observe each enclosed combustion device and flare to determine if it is operating properly. You must determine whether there is a flame present and whether any uncontrolled emissions from the control device are visible with the OGI camera or the technique used to conduct the periodic screening event. During each inspection conducted under § 60.5397b using AVO, you must observe each enclosed combustion device and flare to determine if it is operating properly. Visually confirm that the pilot or combustion flame is lit and that the pilot or combustion flame is operating properly.
(xi) If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d), you must comply with paragraphs (f)(1)(xi)(A) through (E) of this section.
(A) You must maintain the combustion efficiency at or above 95.0 percent. Alternatively, if the alternative test method does not directly monitor combustion efficiency, you must comply with the applicable requirements in paragraphs (f)(1)(xi)(A)( 1) and ( 2) of this section.
( 1 ) Maintain the NHVcz at or above 270 Btu/scf.
( 2 ) For flares or enclosed combustion devices with perimeter assist air, maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the flare or enclosed combustion device is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are only required to comply with the NHVcz limit specified in paragraph (f)(1)(xi)(A)( 1) of this section.
(B) You must calculate the value of the applicable monitored metric(s) in accordance with the approved alternative test method. Compliance with the limit is achieved when the calculated values are within the range specified in paragraph (f)(1)(xi)(A) of this section.
(C) You must conduct monitoring using the alternative test method at all times the affected source is operating, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities, including, as applicable, system accuracy audits and required zero and span adjustments. A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. You are required to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
(D) You may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report values to demonstrate compliance with the limits specified in paragraph (f)(1)(xi)(A) of this section. You must use all the data collected during all other required data collection periods to assess the operation of the control device and associated control system.
(E) Failure to collect required data is a deviation of the monitoring requirements.
(2) You must maintain the records as specified in § 60.5420b(c)(11) and (13).
(3) You must comply with the reporting requirements in § 60.5420b(b)(11) through (13).
* * * * *(h) Process controller affected facility. To demonstrate continuous compliance with GHG and VOC emission standards for your process controller affected facility as required by § 60.5390b, you must comply with paragraphs (h)(1) through (4) of this section, as applicable.
(1) You must demonstrate that your process controller affected facility does not emit any VOC or methane to the atmosphere by meeting the requirements of paragraphs (h)(1)(i) or (ii) of this section.
(i) If you comply by routing the emissions to a process, you must route emissions through a closed vent system and continuously comply with the closed vent system inspection and monitoring requirements of § 60.5416b.
(ii) If you comply by using a self-contained natural gas-driven process controller, you must conduct the no identifiable emissions inspections required by § 60.5416b(b).
(2) For each process controller affected facility located at a site in Alaska that does not have access to electrical power and that complies by reducing methane and VOC emissions from all controllers in the process controller affected facility by 95.0 percent in accordance with § 60.5390b(b)(3), you must route emissions to a control device through a closed vent system and continuously comply with the closed vent requirements of § 60.5416b and the requirements in paragraph (f) of this section for the control device.
(3) You must submit the annual report for your process controller as required in § 60.5420b(b)(1), (7), and (11) through (13), as applicable.
(4) You must maintain the records as specified in § 60.5420b(c)(6), (8), (10), and (12) for each process controller affected facility, as applicable.
(i) Storage vessel affected facility. For each storage vessel affected facility, you must demonstrate continuous compliance with the requirements of § 60.5395b according to paragraphs (i)(1) through (10) of this section, as applicable.
(1) For each storage vessel affected facility complying with the requirements of § 60.5395b(a)(2), you must demonstrate continuous compliance according to paragraphs (i)(5), (9) and (10) of this section.
(2) For each storage vessel affected facility complying with the requirements of § 60.5395b(a)(3), you must demonstrate continuous compliance according to paragraphs (i)(2)(i), (ii), or (iii) of this section, as applicable, and (i)(9) and (10) of this section.
(i) You must maintain the uncontrolled actual VOC emissions at less than 4 tpy and the uncontrolled actual methane emissions at less than 14 tpy from the storage vessel affected facility.
(ii) You must comply with paragraph (i)(5) of this section as soon as liquids from the well are routed to the storage vessel affected facility following fracturing or refracturing according to the requirements of § 60.5395b(a)(3)(i).
(iii) You must comply with paragraph (i)(5) of this section within 30 days of the monthly determination according to the requirements of § 60.5395b(a)(3)(ii), where the monthly emissions determination indicates that VOC emissions from your storage vessel affected facility increase to 4 tpy or greater or methane emissions from your storage vessel affected facility increase to 14 tpy or greater and the increase is not associated with fracturing or refracturing of a well feeding the storage vessel affected facility.
(3) For each storage vessel affected facility or portion of a storage vessel affected facility removed from service, you must demonstrate compliance with the requirements of § 60.5395b(c)(1) or (2) by complying with paragraphs (i)(6), (7), (9), and (10) of this section.
(4) For each storage vessel affected facility or portion of a storage vessel affected facility returned to service, you must demonstrate compliance with the requirements of § 60.5395b(c)(3) and (4) by complying with paragraphs (i)(8) through (10) of this section.
(5) For each storage vessel affected facility, you must comply with paragraphs (i)(5)(i) and (ii) of this section.
(i) You must reduce VOC emissions as specified in § 60.5395b(a)(2).
(ii) For each control device installed to meet the requirements of § 60.5395b(a)(2), you must demonstrate continuous compliance with the performance requirements of § 60.5412b for each storage vessel affected facility using the procedure specified in paragraphs (i)(5)(ii)(A) and (i)(5)(ii)(B) of this section. When routing emissions to a process, you must demonstrate continuous compliance as specified in paragraph (i)(5)(ii)(A) of this section.
(A) You must comply with § 60.5416b for each cover and closed vent system.
(B) You must comply with the requirements specified in paragraph (f) of this section.
(6) You must completely empty and degas each storage vessel, such that each storage vessel no longer contains crude oil, condensate, produced water or intermediate hydrocarbon liquids. For a portion of a storage vessel affected facility to be removed from service, you must completely empty and degas the storage vessel(s), such that the storage vessel(s) no longer contains crude oil, condensate, produced water, or intermediate hydrocarbon liquids. A storage vessel where liquid is left on walls, as bottom clingage, or in pools due to floor irregularity is considered to be completely empty.
(7) You must disconnect the storage vessel(s) from the tank battery by isolating the storage vessel(s) from the tank battery such that the storage vessel(s) is no longer manifolded to the tank battery by liquid or vapor transfer.
(8) You must determine the affected facility status of a storage vessel returned to service as provided in § 60.5365b(e)(6).
(9) You must submit the annual reports as required by § 60.5420b(b)(1), (8), and (11)(i) through (iv).
(10) You must maintain the records as required by § 60.5420b(c)(7) through (10) and (c)(12), as applicable.
* * * * *(k) Sweetening unit affected facility. For each sweetening unit affected facility, you must demonstrate continuous compliance with the requirements of § 60.5405b(b) according to paragraphs (k)(1) through (10) of this section.
(1) You must determine the minimum required continuous reduction efficiency of SO2 emissions (Zc) as required by § 60.5406b(b).
(2) You must determine the emission reduction efficiency (R) achieved by your sulfur reduction technology using the procedures in § 60.5406b(c)(1) through (c)(4).
(3) You must demonstrate compliance with the standard at § 60.5405b(b) by comparing the minimum required sulfur dioxide emission reduction efficiency (Zc) to the emission reduction efficiency achieved by the sulfur recovery technology (R), where R must be greater than or equal to Zc.
(4) You must calibrate, maintain, and operate monitoring devices or perform measurements to determine the accumulation of sulfur product, the H2 S concentration, the average acid gas flow rate, and the sulfur feed rate in accordance with § 60.5407b(a).
(5) You must determine the required SO2 emissions reduction efficiency each 24-hour period in accordance with § 60.5407b(a), § 60.5407b(d), and § 60.5407b(e), as applicable.
(6) You must calibrate, maintain, and operate monitoring devices and continuous emission monitors in accordance with § 60.5407b(b), (f), and (g), if you use an oxidation control system or a reduction control system followed by an incineration device.
(7) You must continuously operate the incineration device, if you use an oxidation control system or a reduction control system followed by an incineration device.
(8) You must calibrate, maintain, and operate a continuous monitoring system to measure the emission rate of reduced sulfur compounds in accordance with § 60.5407b(c), (f), and (g), if you use a reduction control system not followed by an incineration device.
(9) You must submit the reports as required by § 60.5423b(d).
(10) You must maintain the records as required by § 60.5423b(a), (e), and (f), as applicable.
(l) Continuous compliance. For each fugitive emissions components affected facility, you must demonstrate continuous compliance with the requirements of § 60.5397b(a) according to paragraphs (l)(1) through (4) of this section.
(1) Monitoring. You must conduct periodic monitoring surveys as required in § 60.5397b(e) and (g).
(2) Repairs. You must repair each identified source of fugitive emissions as required in § 60.5397b(h).
(3) Reports. You must submit annual reports for fugitive emissions components affected facilities as required in § 60.5420b(b)(1) and (9).
(4) Record s. You must maintain records as specified in § 60.5420b(c)(14).
28. Amend § 60.5416b by revising paragraphs (a) introductory text and (b)(2) to read as follows:
What are the initial and continuous cover and closed vent system inspection and monitoring requirements?* * * * *(a) Inspections for closed vent systems, covers, and bypass devices. If you install a control device or route emissions to a process, you must inspect each closed vent system according to the procedures and schedule specified in paragraphs (a)(1) and (2) of this section, inspect each cover according to the procedures and schedule specified in paragraph (a)(3) of this section, and inspect each bypass device according to the procedures of paragraph (a)(4) of this section, except as provided in paragraphs (b)(7) and (8) of this section.
* * * * *(b) * * *
(2) OGI application. Where OGI is used, the closed vent system, cover, or self-contained process controller is determined to operate with no identifiable emissions if no emissions are imaged during the inspection. Emissions imaged by OGI constitute a deviation of the no identifiable emissions standard until an OGI inspection conducted in accordance with paragraph (b)(1) of this section determines that the closed vent system, cover, or self-contained process controller, as applicable, operates with no identifiable emissions.
* * * * *29. Amend § 60.5417b by revising paragraphs (a), (d)(8) introductory text, (i)(4) and (5), and (j) to read as follows:
What are the continuous monitoring requirements for my control devices?* * * * *(a) For each control device used to comply with the emission reduction standard in § 60.5377b(b) for well affected facilities, § 60.5380b(a)(1) for centrifugal compressor affected facilities, § 60.5385b(d)(2) for reciprocating compressor affected facilities, § 60.5390b(b)(3) for your process controller affected facility in Alaska, § 60.5393b(b)(3) for your pumps affected facility, § 60.5395b(a)(2) for your storage vessel affected facility, or either § 60.5400b(f) or § 60.5401b(e) for your process equipment affected facility, you must install and operate a continuous parameter monitoring system for each control device as specified in paragraphs (c) through (h) of this section, except as provided for in paragraph (b) of this section. If you install and operate a flare in accordance with § 60.5412b(a)(3), you are exempt from the requirements of paragraph (f) of this section. If you operate an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d), you must operate the control device as specified in paragraph (i) of this section instead of using the procedures specified in paragraphs (c) through (h) of this section. You must keep records and report in accordance with paragraph (j) of this section.
* * * * *(d) * * *
(8) For an enclosed combustion device, other than those listed in paragraphs (d)(1) through (3) and (7) of this section, or for a flare, continuous monitoring systems as specified in paragraphs (d)(8)(i) through (iv) of this section and visible emission observations conducted as specified in paragraph (d)(8)(v) of this section. Additionally, for enclosed combustion devices or flares that are air-assisted or steam-assisted, the continuous monitoring systems specified in paragraph (d)(8)(vi) of this section.
* * * * *(i) * * *
(4) If required by § 60.5412b(d)(4), you must conduct the inspections required by paragraph (d)(8)(v) of this section.
(5) If required by § 60.5412b(d)(5), you must install the pilot or combustion flame monitoring system required by paragraph (d)(8)(i) of this section.
* * * * *(j) You must submit annual reports for control devices as required in § 60.5420b(b)(1) and (11). You must maintain records as specified in § 60.5420b(c)(11).
30. Amend § 60.5420b by revising and republishing paragraphs (b), (c), and (d) introductory text to read as follows:
What are my notification, reporting, and recordkeeping requirements?* * * * *(b) Reporting requirements. You must submit annual reports containing the information specified in paragraphs (b)(1) through (14) of this section following the procedure specified in paragraph (b)(15) of this section. You must submit performance test reports as specified in paragraph (b)(12) or (13) of this section, if applicable. 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 paragraphs (b)(1) through (14) of this section. 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. You must submit the information in paragraph (b)(1)(v) of this section, as applicable, for your well affected facility which undergoes a change of ownership during the reporting period, regardless of whether reporting under paragraphs (b)(2) through (4) of this section is required for the well affected facility.
(1) The general information specified in paragraphs (b)(1)(i) through (v) of this section is required for all reports.
(i) The company name, facility site name associated with the affected facility, U.S. Well ID or U.S. Well ID associated with the affected facility, if applicable, 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 and precision of five (5) decimals of a degree using the North American Datum of 1983.
(ii) An identification of each affected facility being included in the annual report.
(iii) Beginning and ending dates of the reporting period.
(iv) 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 (b)(1)(iv).
(v) Identification of each well affected facility for which ownership changed due to sale or transfer of ownership including the United States Well Number; the latitude and longitude coordinates of the well affected facility in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983; and the information in paragraph (b)(1)(v)(A) or (B) of this section, as applicable.
(A) The name and contact information, including the phone number, email address, and mailing address, of the owner or operator to which you sold or transferred ownership of the well affected facility identified in paragraph (b)(1)(v) of this section.
(B) The name and contact information, including the phone number, email address, and mailing address, of the owner or operator from whom you acquired the well affected facility identified in paragraph (b)(1)(v) of this section.
(2) For each well affected facility that is subject to § 60.5375b(a) or (f), the records of each well completion operation conducted during the reporting period, including the information specified in paragraphs (b)(2)(i) through (xiv) of this section, if applicable. In lieu of submitting the records specified in paragraphs (b)(2)(i) through (xiv) of this section, the owner or operator may submit a list of each well completion with hydraulic fracturing completed during the reporting period, and the digital photograph required by paragraph (c)(1)(v) of this section for each well completion. For each well affected facility that routes all flowback entirely through one or more production separators, only the records specified in paragraphs (b)(2)(i) through (iv) and (vi) of this section are required to be reported. For periods where salable gas is unable to be separated, the records specified in paragraphs (b)(2)(iv) and (viii) through (xii) of this section must also be reported, as applicable. For each well affected facility that is subject to § 60.5375b(g), the record specified in paragraph (b)(2)(xv) of this section is required to be reported. For each well affected facility which makes a claim that the exemption in § 60.5375b(h) was met, the records specified in paragraph (b)(2)(i) through (iv) and (b)(2)(xvi) of this section are required to be reported.
(i) Well Completion ID.
(ii) Latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983.
(iii) U.S. Well ID.
(iv) The date and time of the onset of flowback following hydraulic fracturing or refracturing or identification that the well immediately starts production.
(v) The date and time of each attempt to direct flowback to a separator as required in § 60.5375b(a)(1)(ii).
(vi) The date and time that the well was shut in and the flowback equipment was permanently disconnected, or the startup of production.
(vii) The duration (in hours) of flowback.
(viii) The duration (in hours) of recovery and disposition of recovery ( i.e., routed to the gas flow line or collection system, re-injected into the well or another well, used as an onsite fuel source, or used for another useful purpose that a purchased fuel or raw material would serve).
(ix) The duration (in hours) of combustion.
(x) The duration (in hours) of venting.
(xi) The specific reasons for venting in lieu of capture or combustion.
(xii) For any deviations recorded as specified in paragraph (c)(1)(ii) of this section, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation.
(xiii) For each well affected facility subject to § 60.5375b(f), a record of the well type ( i.e., wildcat well, delineation well, or low pressure well (as defined § 60.5430b)) and supporting inputs and calculations, if applicable.
(xiv) For each well affected facility for which you claim an exception under § 60.5375b(a)(2), the specific exception claimed and reasons why the well meets the claimed exception.
(xv) For each well affected facility with less than 300 scf of gas per stock tank barrel of oil produced, the supporting analysis that was performed in order the make that claim, including but not limited to, GOR values for established leases and data from wells in the same basin and field.
(xvi) For each well affected facility which meets the exemption in § 60.5375b(h), a statement that the well completion operation requirements of § 60.5375b(a)(1) through (3) were met.
(3) For each well affected facility that is subject to § 60.5376b(a)(1) or (2), your annual report is required to include the information specified in paragraphs (b)(3)(i) and (ii) of this section, as applicable.
(i) For each well affected facility where all gas well liquids unloading operations comply with § 60.5376b(a)(1), your annual report must include the information specified in paragraphs (b)(3)(i)(A) through (C) of this section, as applicable.
(A) Identification of each well affected facility (U.S. Well ID or U.S. Well ID associated with the well affected facility) that conducts a gas well liquid unloading operation during the reporting period using a method that does not vent to the atmosphere and the technology or technique used. If more than one non-venting technology or technique is used, you must identify all of the differing non-venting liquids unloading methods used during the reporting period.
(B) Number of gas well liquids unloading operations conducted during the year where the well affected facility identified in (b)(3)(i)(A) had unplanned venting to the atmosphere and best management practices were conducted according to your best management practice plan, as required by § 60.5376b(c). If no venting events occurred, the number would be zero. Other reported information required to be submitted where unplanned venting occurs is specified in paragraphs (b)(3)(i)(B)( 1) and ( 2) of this section.
( 1) Log of best management practice plan steps used during the unplanned venting to minimize emissions to the maximum extent possible.
( 2) The number of liquids unloading events during the year where deviations from your best management practice plan occurred, the date and time the deviation began, the duration of the deviation in hours, documentation of why best management practice plan steps were not followed, and what steps, in lieu of your best management practice plan steps, were followed to minimize emissions to the maximum extent possible.
(C) The number of liquids unloading events where unplanned emissions are vented to the atmosphere during a gas well liquids unloading operation where you complied with best management practices to minimize emissions to the maximum extent possible.
(ii) For each well affected facility where all gas well liquids unloading operations comply with § 60.5376b(b) and (c) best management practices, your annual report must include the information specified in paragraphs (b)(3)(ii)(A) through (E) of this section.
(A) Identification of each well affected facility that conducts a gas well liquids unloading during the reporting period.
(B) Number of liquids unloading events conducted during the reporting period.
(C) Log of best management practice plan steps used during the reporting period to minimize emissions to the maximum extent possible.
(D) The number of liquids unloading events during the year that best management practices were conducted according to your best management practice plan.
(E) The number of liquids unloading events during the year where deviations from your best management practice plan occurred, the date and time the deviation began, the duration of the deviation in hours, documentation of why best management practice plan steps were not followed, and what steps, in lieu of your best management practice plan steps, were followed to minimize emissions to the maximum extent possible.
(4) For each associated gas well subject to § 60.5377b, your annual report is required to include the applicable information specified in paragraphs (b)(4)(i) through (vi) of this section, as applicable.
(i) For each associated gas well that complies with § 60.5377b(a)(1), (2), (3), or (4) your annual report is required to include the information specified in paragraphs (b)(4)(i)(A) and (B) of this section.
(A) An identification of each associated gas well constructed, modified, or reconstructed during the reporting period that complies with § 60.5377b(a)(1), (2), (3), or (4).
(B) The information specified in paragraphs (b)(2)(i)(B)( 1) through ( 3) of this section for each incident when the associated gas was temporarily routed to a flare or control device in accordance with § 60.5377b(d).
( 1) The reason in § 60.5377b(d)(1), (2), (3), or (4) for each incident.
( 2) The start date and time of each incident of routing associated gas to the flare or control device, along with the total duration in hours of each incident.
( 3) Documentation that all CVS requirements specified in § 60.5411b(a) and (c) and all applicable flare or control device requirements specified in § 60.5412b were met during each period when the associated gas is routed to the flare or control device.
(ii) For all instances where you temporarily vent the associated gas in accordance with § 60.5377b(e), you must report the information specified in paragraphs (b)(4)(ii)(A) through (D) of this section. This information is required to be reported if you are routinely complying with § 60.5377b(a) or § 60.5377b(f) or temporarily complying with § 60.5377b(d). In addition to this information for each incident, you must report the cumulative duration in hours of venting incidents and the cumulative VOC and methane emissions in pounds for all incidents in the calendar year.
(A) The reason in § 60.5377b(e)(1), (2), or (3) for each incident.
(B) The start date and time of each incident of venting the associated gas, along with the total duration in hours of each incident.
(C) The VOC and methane emissions in pounds that were emitted during each incident.
(D) The total duration of venting for all incidents in the year, along with the cumulative VOC and methane emissions in pounds that were emitted.
(iii) For each associated gas well that complies with the requirements of § 60.5377b(f) your annual report must include the information specified in paragraphs (b)(4)(iii)(A) through (E) of this section. The information in paragraphs (b)(4)(iii)(A) and (B) of this section is only required in the initial annual report.
(A) An identification of each associated gas well that commenced construction between May 7, 2024, and May 7, 2026. This identification must include the certification of why it is infeasible to comply with § 60.5377b(a)(1), (2), (3), or (4) in accordance with § 60.5377b(g).
(B) An identification of each associated gas well that commenced construction between December 6, 2022, and May 7, 2024. This identification must include the certification of why it is infeasible to comply with § 60.5377b(a)(1), (2), (3), or (4) in accordance with § 60.5377b(g).
(C) An identification of each associated gas well modified or reconstructed during the reporting period that complies by routing the gas to a control device that reduces VOC and methane emissions by at least 95.0 percent. This identification must include the certification of why it is infeasible to comply with § 60.5377b(a)(1), (2), (3), or (4) in accordance with § 60.5377b(g).
(D) For each associated gas well that was constructed, modified or reconstructed in a previous reporting period that complies by routing the gas to a control device that reduces VOC and methane emissions by at least 95.0 percent, a re-certification of why it is infeasible to comply with § 60.5377b(a)(1), (2), (3), or (4) in accordance with § 60.5377b(g).
(E) The information specified in paragraphs (b)(11)(i) through (iv) of this section.
(iv) If you comply with § 60.5377b(f) with a control device, identification of the associated gas well using the control device and the information in paragraph (b)(11)(v) of this section.
(v) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(11)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(vi) For each deviation recorded as specified in paragraph (c)(3)(v) of this section, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(5) For each wet seal centrifugal compressor affected facility, the information specified in paragraphs (b)(5)(i) through (v) of this section. For each self-contained wet seal centrifugal compressor, Alaska North Slope centrifugal compressor equipped with sour seal oil separator and capture system, or dry seal centrifugal compressor affected facility, the information specified in paragraphs (b)(5)(vi) through (ix) of this section.
(i) An identification of each centrifugal compressor constructed, modified, or reconstructed during the reporting period.
(ii) For each deviation that occurred during the reporting period and recorded as specified in paragraph (c)(4) of this section, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(iii) If required to comply with § 60.5380b(a)(2) or (3), the information specified in paragraphs (b)(11)(i) through (iv) of this section, as applicable.
(iv) If complying with § 60.5380b(a)(1) with a control device, identification of the centrifugal compressor with the control device and the information in paragraph (b)(11)(v) of this section.
(v) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(11)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(vi) If complying with § 60.5380b(a)(4), (5), or (6) for a self-contained wet seal centrifugal compressor, Alaska North Slope centrifugal compressor equipped with sour seal oil separator and capture system, or dry seal centrifugal compressor requirements, the cumulative number of hours of operation since initial startup, since May 7, 2024, or since the previous volumetric flow rate emissions measurement, as applicable, which have elapsed prior to conducting your volumetric flow rate emission measurement or emissions screening.
(vii) A description of the method used and the results of the volumetric emissions measurement or emissions screening, as applicable.
(viii) Number and type of seals on delay of repair and explanation for each delay of repair.
(ix) Date of planned shutdown(s) that occurred during the reporting period if there are any seals that have been placed on delay of repair.
(6) For each reciprocating compressor affected facility, the information specified in paragraphs (b)(6)(i) through (vii) of this section, as applicable.
(i) The cumulative number of hours of operation since initial startup, since May 7, 2024, since the previous volumetric flow rate measurement, or since the previous reciprocating compressor rod packing replacement, as applicable, which have elapsed prior to conducting your volumetric flow rate measurement or emissions screening. Alternatively, a statement that emissions from the rod packing are being routed to a process or control device through a closed vent system.
(ii) If applicable, for each deviation that occurred during the reporting period and recorded as specified in paragraph (c)(5)(i) of this section, the date and time the deviation began, duration of the deviation in hours and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(iii) A description of the method used and the results of the volumetric flow rate measurement or emissions screening, as applicable.
(iv) If complying with § 60.5385b(d)(1) or (2), the information in paragraphs (b)(11)(i) through (iv) of this section. If complying by routing emissions to a control device, as required in § 60.5385b(d)(2), the information in paragraph (b)(11)(v) of this section.
(v) Number and type of rod packing replacements/repairs on delay of repair and explanation for each delay of repair.
(vi) Date of planned shutdown(s) that occurred during the reporting period if there are any rod packing replacements/repairs that have been placed on delay of repair.
(vii) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(11)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(7) For each process controller affected facility, the information specified in paragraphs (b)(7)(i) through (iii) of this section in your initial annual report and in subsequent annual reports for each process controller affected facility that is constructed, modified, or reconstructed during the reporting period. Each annual report must contain the information specified in paragraphs (b)(7)(iv) through (x) of this section for each process controller affected facility.
(i) An identification of each process controller that is driven by natural gas, as required by § 60.5390b(d), that allows traceability to the records required in paragraph (c)(6)(i) of this section.
(ii) For each process controller in the affected facility complying with § 60.5390b(a), you must report the information specified in paragraphs (b)(7)(ii)(A) and (B) of this section, as applicable.
(A) An identification of each process controller complying with § 60.5390b(a) by routing the emissions to a process.
(B) An identification of each process controller complying with § 60.5390b(a) by using a self-contained natural gas-driven process controller.
(iii) For each process controller affected facility located at a site in Alaska that does not have access to electrical power and that complies with § 60.5390b(b), you must report the information specified in paragraphs (b)(7)(iii)(A), (B), or (C) of this section, as applicable.
(A) For each process controller complying with § 60.5390b(b)(1) process controller bleed rate requirements, you must report the information specified in paragraphs (b)(7)(iii)(A)( 1) and ( 2) of this section.
( 1) The identification of process controllers designed and operated to achieve a bleed rate less than or equal to 6 scfh.
( 2) Where necessary to meet a functional need, the identification and demonstration why it is necessary to use a process controller with a natural gas bleed rate greater than 6 scfh.
(B) An identification of each intermittent vent process controller complying with the requirements in paragraph § 60.5390b(b)(2).
(C) An identification of each process controller complying with the requirements in § 60.5390b(b) by routing emissions to a control device in accordance with § 60.5390b(b)(3).
(iv) Identification of each process controller which changes its method of compliance during the reporting period and the applicable information specified in paragraphs (b)(7)(v) through (ix) of this section for the new method of compliance.
(v) For each process controller in the affected facility complying with the requirements of § 60.5390b(a) by routing the emissions to a process, you must report the information specified in (b)(11)(i) through (iii) of this section.
(vi) For each process controller in the affected facility complying with the requirements of § 60.5390b(a) by using a self-contained natural gas-driven process controller, you must report the information specified in paragraphs (b)(7)(vi)(A) and (B) of this section.
(A) Dates of each inspection required under § 60.5416b(b); and
(B) Each defect or leak identified during each natural gas-driven-self-contained process controller system inspection, and the date of repair or date of anticipated repair if repair is delayed.
(vii) For each process controller in the affected facility complying with the requirements of § 60.5390b(b)(2), you must report the information specified in paragraphs (b)(7)(vii)(A) and (B) of this section.
(A) Dates and results of the intermittent vent process controller monitoring required by § 60.5390b(b)(2)(ii).
(B) For each instance in which monitoring identifies emissions to the atmosphere from an intermittent vent controller during idle periods, the date of repair or replacement or the date of anticipated repair or replacement if the repair or replacement is delayed, and the date and results of the re-survey after repair or replacement.
(viii) For each process controller affected facility complying with § 60.5390b(b)(3) by routing emissions to a control device, you must report the information specified in paragraph (b)(11) of this section.
(ix) For each deviation that occurred during the reporting period, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(x) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(7)(vi) and (vii) and (b)(11)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(8) For each storage vessel affected facility, the information in paragraphs (b)(8)(i) through (x) of this section.
(i) An identification, including the location, of each storage vessel affected facility, including those for which construction, modification, or reconstruction commenced during the reporting period, and those provided in previous reports. The location of the storage vessel affected facility shall be in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983.
(ii) Documentation of the methane and VOC emission rate determination according to § 60.5365b(e)(1) for each tank battery that became an affected facility during the reporting period or is returned to service during the reporting period.
(iii) For each deviation that occurred during the reporting period and recorded as specified in paragraph (c)(7)(iii) of this section, the date and time the deviation began, duration of the deviation in hours and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(iv) For each storage vessel affected facility constructed, modified, reconstructed, or returned to service during the reporting period complying with § 60.5395b(a)(2) with a control device, report the identification of the storage vessel affected facility with the control device and the information in paragraph (b)(11)(v) of this section.
(v) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(11)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(vi) If required to comply with § 60.5395b(b)(1), the information in paragraphs (b)(11)(i) through (iv) of this section.
(vii) You must identify each storage vessel affected facility that is removed from service during the reporting period as specified in § 60.5395b(c)(1)(ii), including the date the storage vessel affected facility was removed from service. You must identify each storage vessel that that is removed from service from a storage vessel affected facility during the reporting period as specified in § 60.5395b(c)(2)(iii), including identifying the impacted storage vessel affected facility and the date each storage vessel was removed from service.
(viii) You must identify each storage vessel affected facility or portion of a storage vessel affected facility returned to service during the reporting period as specified in § 60.5395b(c)(4), including the date the storage vessel affected facility or portion of a storage vessel affected facility was returned to service.
(ix) You must identify each storage vessel affected facility that no longer complies with § 60.5395b(a)(3) and instead complies with § 60.5395b(a)(2). You must identify whether the change in the method of compliance was due to fracturing or refracturing or whether the change was due to an increase in the monthly emissions determination. If the change was due to an increase in the monthly emissions determination, you must provide documentation of the emissions rate. You must identify the date that you complied with § 60.5395b(a)(2) and must submit the information in (b)(8)(iii) through (vii) of this section.
(x) You must submit a statement that you are complying with § 60.112b(a)(1) or (2), if applicable, in your initial annual report.
(9) For the fugitive emissions components affected facility, report the information specified in paragraphs (b)(9)(i) through (v) of this section, as applicable.
(i)(A) 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.
(B) For the fugitive emissions components affected facility at a well site or centralized production facility that became an affected facility during the reporting period, you must include the date of the startup of production or the date of the first day of production after modification. 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.
(C) For the fugitive emissions components affected facility at a well site, you must specify what type of well site it is ( i.e., single wellhead only well site, small wellsite, multi-wellhead only well site, or a well site with major production and processing equipment).
(D) For the fugitive emissions components affected facility at a well site where during the reporting period you complete the removal of all major production and processing equipment such that the well site contains only one or more wellheads, you must include the date of the change to status as a wellhead only well site.
(E) For the fugitive emissions components affected facility at a well site where you previously reported under paragraph (b)(9)(i)(D) of this section the removal of all major production and processing equipment and during the reporting period major production and processing equipment is added back to the well site, the date that the first piece of major production and processing equipment is added back to the well site.
(F) For the fugitive emissions components affected facility at a well site where during the reporting period you undertake well closure requirements, the date of the cessation of production from all wells at the well site, the date you began well closure activities at the well site, and the dates of the notifications submitted in accordance with paragraph (a)(4) of this section.
(ii) For each fugitive emissions monitoring survey performed during the annual reporting period, the information specified in paragraphs (b)(9)(ii)(A) through (G) of this section.
(A) Date of the survey.
(B) Monitoring instrument or, if the survey was conducted by AVO methods, notation that AVO was used.
(C) 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.
(D) Number and type of components for which fugitive emissions were detected.
(E) Number and type of fugitive emissions components that were not repaired as required in § 60.5397b(h).
(F) Number and type of fugitive emission components (including designation as difficult-to-monitor or unsafe-to-monitor, if applicable) on delay of repair and explanation for each delay of repair.
(G) Date of planned shutdown(s) that occurred during the reporting period if there are any components that have been placed on delay of repair.
(iii) For the fugitive emissions components affected facility complying with an alternative fugitive emissions standard under § 60.5399b, in lieu of the information specified in paragraphs (b)(9)(i) and (ii) of this section, you must provide the information specified in paragraphs (b)(9)(iii)(A) through (C) of this section.
(A) The alternative standard with which you are complying.
(B) The site-specific reports specified by the specific alternative fugitive emissions standard, submitted in the format in which they were submitted to the state, local, or Tribal authority. If the report is in hard copy, you must scan the document and submit it as an electronic attachment to the annual report required in paragraph (b) of this section.
(C) If the report specified by the specific alternative fugitive emissions standard is not site-specific, you must submit the information specified in paragraphs (b)(9)(i) and (ii) of this section for each individual site complying with the alternative standard.
(iv) For well closure activities which occurred during the reporting period, the information in paragraphs (b)(9)(iv)(A) and (B) of this section.
(A) A status report with dates for the well closure activities schedule developed in the well closure plan. If all steps in the well closure plan are completed in the reporting period, the date that all activities are completed.
(B) If an OGI survey is conducted during the reporting period, the information in paragraphs (b)(9)(iv)(B)( 1) through ( 3) of this section.
( 1) Date of the OGI survey.
( 2) Monitoring instrument used.
( 3) A statement that no fugitive emissions were found, or if fugitive emissions were found, a description of the steps taken to eliminate those emissions, the date of the resurvey, the results of the resurvey, and the date of the final resurvey which detected no emissions.
(v) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(9)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(10) For each pump affected facility, the information specified in paragraphs (b)(10)(i) through (iv) of this section in your initial annual report and in subsequent annual reports for each pump affected facility that is constructed, modified, or reconstructed during the reporting period. Each annual report must contain the information specified in paragraphs (b)(10)(v) through (ix) of this section for each pump affected facility.
(i) The identification of each of your pumps that are driven by natural gas, as required by § 60.5393b(a) that allows traceability to the records required by paragraph (c)(15)(i) of this section.
(ii) For each pump affected facility for which there is a control device on site but it does not achieve a 95.0 percent emissions reduction, the certification that there is a control device available on site but it does not achieve a 95.0 percent emissions reduction required under § 60.5393b(b)(5). You must also report the emissions reduction percentage the control device is designed to achieve.
(iii) For each pump affected facility for which there is no control device or vapor recovery unit on site, the certification required under § 60.5393b(b)(6) that there is no control device or vapor recovery unit on site.
(iv) For each pump affected facility for which it is technically infeasible to route the emissions to a process or control device, the certification of technically infeasibility required under § 60.5393b(b)(7).
(v) For any pump affected facility which has previously reported as required under paragraph (b)(10)(i) through (iv) of this section and for which a change in the reported condition has occurred during the reporting period, provide the identification of the pump affected facility and the date that the pump affected facility meets one of the change conditions described in paragraphs (b)(10)(v)(A), (B), or (C) of this section.
(A) If you install a control device or vapor recovery unit, you must report that a control device or vapor recovery unit has been added to the site and that the pump affected facility now is required to comply with § 60.5393b(b)(2), (3) or (5), as applicable.
(B) If your pump affected facility previously complied with § 60.5393b(b)(2), (3) or (5) by routing emissions to a process or a control device and the process or control device is subsequently removed from the site or is no longer available such that there is no ability to route the emissions to a process or control device at the site, or that it is not technically feasible to capture and route the emissions to another control device or process located on site, report that you are no longer complying with the applicable requirements of § 60.5393b(b)(2), (3), or (5) and submit the information provided in paragraphs (b)(10)(v)(B)( 1) or ( 2) of this section.
( 1) Certification that there is no control device or vapor recovery unit on site.
( 2) Certification of the engineering assessment that it is technically infeasible to capture and route the emissions to another control device or process located on site.
(C) If any pump affected facility or individual natural gas-driven pump changes its method of compliance during the reporting period other than for the reasons specified in paragraphs (10)(v)(A) and (B) of this section, identify the new compliance method for each natural gas-driven pump within the affected facility which changes its method of compliance during the reporting period and provide the applicable information specified in paragraphs (b)(10)(ii) through (iv) and (vi) through (viii) of this section for the new method of compliance.
(vi) For each pump affected facility complying with the requirements of § 60.5393b(a), (b)(1), or (b)(3) by routing the emissions to a process, you must report the information specified in paragraphs (b)(11)(i) through (iv) of this section.
(vii) For each pump affected facility complying with the requirements of § 60.5393b(b)(3) or (5) by routing the emissions to a control device, you must report the information required under paragraphs (b)(11)(i) through (v) of this section.
(viii) For each deviation that occurred during the reporting period, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(ix) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (b)(11)(i) and (ii) of this section, you must provide the information specified in § 60.5424b.
(11) For each well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment affected facility which uses a closed vent system routed to a control device to meet the emissions reduction standard, you must submit the information in paragraphs (b)(11)(i) through (v) of this section. For each reciprocating compressor, process controller, pump, storage vessel, or process unit equipment which uses a closed vent system to route to a process, you must submit the information in paragraphs (b)(11)(i) through (iv) of this section. For each centrifugal compressor, reciprocating compressor, and storage vessel equipped with a cover, you must submit the information in paragraphs (b)(11)(i) and (ii) of this section.
(i) Dates of each inspection required under § 60.5416b(a) and (b).
(ii) Each defect or emissions identified during each inspection and the date of repair or the date of anticipated repair if the repair is delayed.
(iii) Date and time of each bypass alarm or each instance the key is checked out if you are subject to the bypass requirements of § 60.5416b(a)(4).
(iv) You must submit the certification signed by the qualified professional engineer or in-house engineer according to § 60.5411b(c) for each closed vent system routing to a control device or process in the reporting year in which the certification is signed.
(v) If you comply with the emissions standard for your well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment affected facility with a control device, the information in paragraphs (b)(11)(v)(A) through (L) of this section, unless you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d). If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d), the information in paragraphs (b)(11)(v)(A) through (C) and (L) through (P) of this section.
(A) Identification of the control device.
(B) Make, model, and date of installation of the control device.
(C) Identification of the affected facility controlled by the device.
(D) For each continuous parameter monitoring system used to demonstrate compliance for the control device, a unique continuous parameter monitoring system identifier and the make, model number, and date of last calibration check of the continuous parameter monitoring system.
(E) For each instance where there is a deviation of the control device in accordance with § 60.5417b(g)(1) through (3) or (g)(5) through (7) include the date and time the deviation began, the duration of the deviation in hours, the type of the deviation ( e.g., NHV operating limit, lack of pilot or combustion flame, condenser efficiency, bypass line flow, visible emissions), and cause of the deviation.
(F) For each instance where there is a deviation of the continuous parameter monitoring system in accordance with § 60.5417b(g)(4) include the date and time the deviation began, the duration of the deviation in hours, and cause of the deviation.
(G) For each visible emissions test following return to operation from a maintenance or repair activity, the date of the visible emissions test or observation of the video surveillance output, the length of the observation in minutes, and the number of minutes for which visible emissions were present.
(H) If a performance test was conducted on the control device during the reporting period, provide the date the performance test was conducted. Submit the performance test report following the procedures specified in paragraph (b)(12) of this section.
(I) If a demonstration of the NHV of the inlet gas to the enclosed combustion device or flare was conducted during the reporting period in accordance with § 60.5417b(d)(8)(iii), an indication of whether this is a re-evaluation of vent gas NHV and the reason for the re-evaluation; the applicable required minimum vent gas NHV; if twice daily samples of the vent stream were taken, the number of hourly average NHV values that are less than 1.2 times the applicable required minimum NHV; if continuous NHV sampling of the vent stream was conducted, the number of hourly average NHV values that are less than the required minimum vent gas NHV; if continuous combustion efficiency monitoring was conducted using an alternative test method approved under § 60.5412b(d), the number of values of the combustion efficiency that were less than 95.0 percent; the resulting determination of whether NHV monitoring is required or not in accordance with § 60.5417b(d)(8)(iii)(D) or (H); and an indication of whether the enclosed combustion device or flare has the potential to receive inert gases, and if so, whether the sampling included periods where the highest percentage of inert gases were sent to the enclosed combustion device or flare.
(J) If a demonstration was conducted in accordance with § 60.5417b(d)(8)(iv) that the maximum potential pressure of units manifolded to an enclosed combustion device or flare cannot cause the maximum inlet flow rate established in accordance with § 60.5417b(f)(1) or a flare tip velocity limit of 18.3 meter/second (60 feet/second) to be exceeded, an indication of whether this is a re-evaluation of the gas flow and the reason for the re-evaluation; the demonstration conducted; and applicable engineering calculations.
(K) For each periodic sampling event conducted under § 60.5417b(d)(8)(iii)(G), provide the date of the sampling, the required minimum vent gas NHV, and the NHV value for each vent gas sample.
(L) For each flare and enclosed combustion device, provide the date each device is observed with OGI in accordance with § 60.5415b(f)(1)(x) and whether uncombusted emissions were present. Provide the date each device was visibly observed during an AVO inspection in accordance with § 60.5415b(f)(1)(x), whether the pilot or combustion flame was lit at the time of observation, and whether the device was found to be operating properly.
(M) An identification of the alternative test method used.
(N) For each instance where there is a deviation of the control device in accordance with § 60.5417b(i)(6)(i) or (iii) through (v) include the date and time the deviation began, the duration of the deviation in hours, the type of the deviation ( e.g., NHVcz operating limit, lack of pilot or combustion flame, visible emissions), and cause of the deviation.
(O) For each instance where there is a deviation of the data availability in accordance with § 60.5417b(i)(6)(ii) include the date of each operating day when monitoring data are not available for at least 75 percent of the operating hours.
(P) If no deviations occurred under paragraphs (b)(11)(v)(N) or (O) of this section, a statement that there were no deviations for the control device during the annual report period.
(Q) Any additional information required to be reported as specified by the Administrator as part of the alternative test method approval under § 60.5412b(d).
(12) Within 60 days after the date of completing each performance test (see § 60.8) required by this subpart, except testing conducted by the manufacturer as specified in § 60.5413b(d), you must submit the results of the performance test following the procedures specified in paragraph (d) of this section. Data collected using test methods that are supported by the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT website ( https://www.epa.gov/electronic-reporting-air-emissions/electronic-reporting-tool-ert) at the time of the test must be submitted in a file format generated using the EPA's ERT. Alternatively, you may submit an electronic file consistent with the extensible markup language (XML) schema listed on the EPA's ERT website. Data collected using test methods that are not supported by the EPA's ERT as listed on the EPA's ERT website at the time of the test must be included as an attachment in the ERT or alternate electronic file.
(13) For combustion control devices tested by the manufacturer in accordance with § 60.5413b(d), an electronic copy of the performance test results required by § 60.5413b(d) shall be submitted via email to Oil_and_Gas_PT@EPA.GOV unless the test results for that model of combustion control device are posted at the following website: https://www.epa.gov/controlling-air-pollution-oil-and-natural-gas-industry.
(14) 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.
(15) 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 following the procedure specified in paragraph (d) of this section. 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.
(c) Recordkeeping requirements. You must maintain the records identified as specified in § 60.7(f) and in paragraphs (c)(1) through (15) of this section. 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.
(1) The records for each well affected facility subject to the well completion operation standards of § 60.5375b, as specified in paragraphs (c)(1)(i) through (vii) of this section, as applicable. For each well affected facility subject to the well completion operations of § 60.5375b, for which you make a claim that the well affected facility is not subject to the requirements for well completions pursuant to § 60.5375b(g), you must maintain the record in paragraph (c)(1)(vi) of this section, only. For each well affected facility which meets the exemption in § 60.5375b(h) for well completion operations ( i.e., an existing well is hydraulically refractured), you must maintain the records in paragraph (c)(1)(viii), only. For each well affected facility that routes flowback entirely through one or more production separators that are designed to accommodate flowback, only records of the United States Well Number, the latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983, the Well Completion ID, and the date and time of startup of production are required. For periods where salable gas is unable to be separated, records of the date and time of onset of flowback, the duration and disposition of recovery, the duration of combustion and venting (if applicable), reasons for venting (if applicable), and deviations are required.
(i) Records identifying each well completion operation for each well affected facility.
(ii) Records of deviations in cases where well completion operations with hydraulic fracturing were not performed in compliance with the requirements specified in § 60.5375b, including the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(iii) You must maintain the records specified in paragraphs (c)(1)(iii)(A) through (C) of this section.
(A) For each well affected facility required to comply with the requirements of § 60.5375b(a), you must record: The latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983; the United States Well Number; the date and time of the onset of flowback following hydraulic fracturing or refracturing; the date and time of each attempt to direct flowback to a separator as required in § 60.5375b(a)(1)(ii); the date and time of each occurrence of returning to the initial flowback stage under § 60.5375b(a)(1)(i); and the date and time that the well was shut in and the flowback equipment was permanently disconnected, or the startup of production; the duration of flowback; duration of recovery and disposition of recovery ( i.e., routed to the gas flow line or collection system, re-injected into the well or another well, used as an onsite fuel source, or used for another useful purpose that a purchased fuel or raw material would serve); duration of combustion; duration of venting; and specific reasons for venting in lieu of capture or combustion. The duration must be specified in hours. In addition, for wells where it is technically infeasible to route the recovered gas as specified in § 60.5375b(a)(1)(ii), you must record the reasons for the claim of technical infeasibility with respect to all four options provided in § 60.5375b(a)(1)(ii).
(B) For each well affected facility required to comply with the requirements of § 60.5375b(f), you must record: Latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983; the United States Well Number; the date and time of the onset of flowback following hydraulic fracturing or refracturing; the date and time that the well was shut in and the flowback equipment was permanently disconnected, or the startup of production; the duration of flowback; duration of combustion; duration of venting; and specific reasons for venting in lieu combustion. The duration must be specified in hours.
(C) For each well affected facility for which you make a claim that it meets the criteria of § 60.5375b(a)(1)(iii)(A), you must maintain the following:
( 1) The latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983; the United States Well Number; the date and time of the onset of flowback following hydraulic fracturing or refracturing; the date and time that the well was shut in and the flowback equipment was permanently disconnected, or the startup of production; the duration of flowback; duration of recovery and disposition of recovery ( i.e., routed to the gas flow line or collection system, re-injected into the well or another well, used as an onsite fuel source, or used for another useful purpose that a purchased fuel or raw material would serve); duration of combustion; duration of venting; and specific reasons for venting in lieu of capture or combustion. The duration must be specified in hours.
( 2) If applicable, records that the conditions of § 60.5375b(a)(1)(iii)(A) are no longer met and that the well completion operation has been stopped and a separator installed. The records shall include the date and time the well completion operation was stopped and the date and time the separator was installed.
( 3) A record of the claim signed by the certifying official that no liquids collection is at the well site. The claim must include 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.
(iv) For each well affected facility for which you claim an exception under § 60.5375b(a)(2), you must record: The latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983; the United States Well Number; the specific exception claimed; the starting date and ending date for the period the well operated under the exception; and an explanation of why the well meets the claimed exception.
(v) For each well affected facility required to comply with both § 60.5375b(a)(1) and (2), if you are using a digital photograph in lieu of the records required in paragraphs (c)(1)(i) through (iv) of this section, you must retain the records of the digital photograph as specified in § 60.5410b(a)(4).
(vi) For each well affected facility for which you make a claim that the well affected facility is not subject to the well completion standards according to § 60.5375b(g), you must maintain:
(A) A record of the analysis that was performed in order the make that claim, including but not limited to, GOR values for established leases and data from wells in the same basin and field;
(B) The latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983; the United States Well Number;
(C) A record of the claim signed by the certifying official. The claim must include 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.
(vii) For each well affected facility subject to § 60.5375b(f), a record of the well type ( i.e., wildcat well, delineation well, or low pressure well (as defined § 60.5430b)) and supporting inputs and calculations, if applicable.
(viii) For each well affected facility which makes a claim it meets the exemption at § 60.5375b(h), a record of the latitude and longitude of the well in decimal degrees to an accuracy and precision of five (5) decimals of a degree using North American Datum of 1983; the United States Well Number; the date and time of the onset of flowback following hydraulic fracturing or refracturing and a record of the claim that the well completion operation requirements of § 60.5375b(a)(1) through (3) were met.
(2) For each gas well liquids unloading operation at your well affected facility that is subject to § 60.5376b(a)(1) or (2), the records of each gas well liquids unloading operation conducted during the reporting period, including the information specified in paragraphs (c)(2)(i) through (iii) of this section, as applicable.
(i) For each gas well liquids unloading operation that complies with § 60.5376b(a)(1) by performing all liquids unloading events without venting of methane and VOC emissions to the atmosphere, comply with the recordkeeping requirements specified in paragraphs (c)(2)(i)(A) and (B) of this section.
(A) Identification of each well ( i.e., U.S. Well ID or U.S. Well ID associated with the well affected facility) that conducts a gas well liquids unloading operation during the reporting period without venting of methane and VOC emissions and the non-venting methane and VOC gas well liquids unloading method used. If more than one non-venting method is used, you must maintain records of all the differing non-venting liquids unloading methods used at the well affected facility complying with § 60.5376b(a)(1).
(B) Number of events where unplanned emissions are vented to the atmosphere during a gas well liquids unloading operation where you complied with best management practices to minimize emissions to the maximum extent possible.
(ii) For each gas well liquids unloading operation that complies with § 60.5376b(b) and (c) best management practices, maintain records documenting information specified in paragraphs (c)(2)(ii)(A) through (D) of this section.
(A) Identification of each well affected facility that conducts liquids unloading during the reporting period that employs best management practices to minimize emissions to the maximum extent possible.
(B) Documentation of your best management practice plan developed under paragraph § 60.5376b(c). You may update your best management practice plan to include additional steps which meet the criteria in § 60.5376b(c).
(C) A log of each best management practice plan step taken to minimize emissions to the maximum extent possible for each gas well liquids unloading event.
(D) Documentation of each gas well liquids unloading event where deviations from your best management practice plan steps occurred, the date and time the deviation began, the duration of the deviation, documentation of best management practice plan steps not followed, and the steps taken in lieu of your best management practice plan steps during those events to minimize emissions to the maximum extent possible.
(iii) For each well affected facility that reduces methane and VOC emissions from well affected facility gas wells that unload liquids by 95.0 percent by routing emissions to a control device through closed vent system under § 60.5376b(g), you must maintain the records in paragraphs (c)(2)(iii)(A) through (E) of this section.
(A) If you comply with the emission reduction standard with a control device, the information for each control device in paragraph (c)(11) of this section.
(B) Records of the closed vent system inspection as specified paragraph (c)(8) of this section.
(C) Records of the cover inspections as specified in paragraph (c)(9) of this section.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(10) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(12) of this section.
(3) For each associated gas well, you must maintain the applicable records specified in paragraphs (c)(3)(i) or (ii) and (c)(3)(iv) of this section.
(i) For each associated gas well that complies with the requirements of § 60.5377b(a)(1), (2), (3), or (4), you must keep the records specified in paragraphs (c)(3)(i)(A) and (B).
(A) Documentation of the specific method(s) in § 60.5377b(a)(1), (2), (3), or (4) that is used.
(B) For instances where you temporarily route the associated gas to a flare or control device in accordance with § 60.5377b(d), you must keep the records specified in paragraphs (c)(3)(i)(B)( 1) through ( 3).
( 1) The reason in § 60.5377b(d)(1), (2), (3), or (4) for each incident.
( 2) The date of each incident, along with the times when routing the associated gas to the flare or control device started and ended, along with the total duration of each incident.
( 3) Documentation that all CVS requirements specified in § 60.5411b(a) and (c) and all applicable flare or control device requirements specified in § 60.5412b are met during each period when the associated gas is routed to the flare or control device.
(ii) For instances where you temporarily vent the associated gas in accordance with § 60.5377b(e), you must keep the records specified in paragraphs (c)(3)(ii)(A) through (D). These records are required if you are routinely complying with § 60.5377b(a) or § 60.5377b(f) or temporarily complying with § 60.5377b(d).
(A) The reason in § 60.5377b(e)(1), (2), or (3) for each incident.
(B) The date of each incident, along with the times when venting the associated gas started and ended, along with the total duration of each incident.
(C) The VOC and methane emissions that were emitted during each incident.
(D) The cumulative duration of venting incidents and VOC and methane emissions for all incidents in each calendar year.
(iii) For each associated gas well that complies with the requirements of § 60.5377b(f) because it has demonstrated that it is not feasible to comply with § 60.5377b(a)(1), (2), (3), and (4) due to technical reasons in accordance with § 60.5377b(g), records of each annual demonstration and certification of the technical reason that it is not feasible to comply with § 60.5377b(a)(1), (2), (3), and (4) in accordance with § 60.5377b(g).
(iv) For each associated gas well that complies with the requirements of § 60.5377b(f), meet the recordkeeping requirements specified in paragraphs (c)(3)(iv)(A) through (E).
(A) Identification of each instance when associated gas was vented and not routed to a control device that reduces VOC and methane emissions by at least 95.0 percent.
(B) If you comply with the emission reduction standard in § 60.5377b with a control device, the information for each control device in paragraphs (c)(11) and (13) of this section.
(C) Records of the closed vent system inspection as specified paragraph (c)(8) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must maintain records of the information specified in § 60.5424b.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(10) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(12) of this section.
(v) Records of each deviation, the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(4) For each centrifugal compressor affected facility, you must maintain the records specified in paragraphs (c)(4)(i) through (iii) of this section.
(i) For each centrifugal compressor affected facility, you must maintain records of deviations in cases where the centrifugal compressor was not operated in compliance with the requirements specified in § 60.5380b, including a description of each deviation, the date and time each deviation began and the duration of each deviation.
(ii) For each wet seal compressor complying with the emissions reduction standard in § 60.5380b(a)(1), you must maintain the records in paragraphs (c)(4)(ii)(A) through (E) of this section. For each wet seal compressor complying with the alternative standard in § 60.5380b(a)(3) by routing the closed vent system to a process, you must maintain the records in paragraphs (c)(4)(ii)(B) through (E) of this section.
(A) If you comply with the emission reduction standard in § 60.5380b(a)(1) with a control device, the information for each control device in paragraph (c)(11) of this section.
(B) Records of the closed vent system inspection as specified paragraph (c)(8) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must maintain the information specified in § 60.5424b.
(C) Records of the cover inspections as specified in paragraph (c)(9) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (c)(9) of this section, you must maintain the information specified in § 60.5424b.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(10) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(12) of this section.
(iii) For each centrifugal compressor affected facility using a self-contained wet seal compressor, centrifugal compressor equipped with sour seal oil separator and capture system, or dry seal compressor complying with the standard in § 60.5380b(a)(4), (5) or (6), you must maintain the records specified in paragraphs (c)(4)(iii)(A) through (H) of this section.
(A) Records of the cumulative number of hours of operation since initial startup, since May 7, 2024, or since the previous volumetric flow rate measurement, as applicable.
(B) A description of the method used and the results of the volumetric flow rate measurement or emissions screening, as applicable.
(C) Records for all flow meters, composition analyzers and pressure gauges used to measure volumetric flow rates as specified in paragraphs (c)(4)(iii)(C)( 1) through ( 6).
( 1) Description of standard method published by a consensus-based standards organization or industry standard practice.
( 2) Records of volumetric flow rate emissions calculations conducted according to paragraphs § 60.5380b(a)(4) through (6), as applicable.
( 3) Records of manufacturer's operating procedures and measurement methods.
( 4) Records of manufacturer's recommended procedures or an appropriate industry consensus standard method for calibration and results of calibration, recalibration, and accuracy checks.
( 5) Records which demonstrate that measurements at the remote location(s) can, when appropriate correction factors are applied, reliably and accurately represent the actual temperature or total pressure at the flow meter under all expected ambient conditions. You must include the date of the demonstration, the data from the demonstration, the mathematical correlation(s) between the remote readings and actual flow meter conditions derived from the data, and any supporting engineering calculations. If adjustments were made to the mathematical relationships, a record and description of such adjustments.
( 6) Record of each initial calibration or a recalibration which failed to meet the required accuracy specification and the date of the successful recalibration.
(D) Date when performance-based volumetric flow rate is exceeded.
(E) The date of successful repair of the compressor seal, including follow-up performance-based volumetric flow rate measurement to confirm successful repair.
(F) Identification of each compressor seal placed on delay of repair and explanation for each delay of repair.
(G) For each compressor seal or part needed for repair placed on delay of repair because of replacement seal or part unavailability, the operator must document: the date the seal or part was added to the delay of repair list, the date the replacement seal or part was ordered, the anticipated seal or part delivery date (including any estimated shipment or delivery date provided by the vendor), and the actual arrival date of the seal or part.
(H) Date of planned shutdowns that occur while there are any seals or parts that have been placed on delay of repair.
(5) For each reciprocating compressor affected facility, you must maintain the records in paragraphs (c)(5)(i) through (x) and (c)(8) through (13) of this section, as applicable. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424b.
(i) For each reciprocating compressor affected facility, you must maintain records of deviations in cases where the reciprocating compressor was not operated in compliance with the requirements specified in § 60.5385b, including a description of each deviation, the date and time each deviation began and the duration of each deviation in hours.
(ii) Records of the date of installation of a rod packing emissions collection system and closed vent system as specified in § 60.5385b(d).
(iii) Records of the cumulative number of hours of operation since initial startup, since May 7, 2024, or since the previous volumetric flow rate measurement, as applicable. Alternatively, a record that emissions from the rod packing are being routed to a process through a closed vent system.
(iv) A description of the method used and the results of the volumetric flow rate measurement or emissions screening, as applicable.
(v) Records for all flow meters, composition analyzers and pressure gauges used to measure volumetric flow rates as specified in paragraphs (c)(5)(v)(A) through (F).
(A) Description of standard method published by a consensus-based standards organization or industry standard practice.
(B) Records of volumetric flow rate calculations conducted according to paragraphs § 60.5385b(b) or (c), as applicable.
(C) Records of manufacturer operating procedures and measurement methods.
(D) Records of manufacturer's recommended procedures or an appropriate industry consensus standard method for calibration and results of calibration, recalibration, and accuracy checks.
(E) Records which demonstrate that measurements at the remote location(s) can, when appropriate correction factors are applied, reliably and accurately represent the actual temperature or total pressure at the flow meter under all expected ambient conditions. You must include the date of the demonstration, the data from the demonstration, the mathematical correlation(s) between the remote readings and actual flow meter conditions derived from the data, and any supporting engineering calculations. If adjustments were made to the mathematical relationships, a record and description of such adjustments.
(F) Record of each initial calibration or a recalibration which failed to meet the required accuracy specification and the date of the successful recalibration.
(vi) Date when performance-based volumetric flow rate is exceeded.
(vii) The date of successful replacement or repair of reciprocating compressor rod packing, including follow-up performance-based volumetric flow rate measurement to confirm successful repair.
(viii) Identification of each reciprocating compressor placed on delay of repair because of rod packing or part unavailability and explanation for each delay of repair.
(ix) For each reciprocating compressor that is placed on delay of repair because of replacement rod packing or part unavailability, the operator must document: the date the rod packing or part was added to the delay of repair list, the date the replacement rod packing or part was ordered, the anticipated rod packing or part delivery date (including any estimated shipment or delivery date provided by the vendor), and the actual arrival date of the rod packing or part.
(x) Date of planned shutdowns that occur while there are any reciprocating compressors that have been placed on delay of repair due to the unavailability of rod packing or parts to conduct repairs.
(6) For each process controller affected facility, you must maintain the records specified in paragraphs (c)(6)(i) through (vii) of this section.
(i) Records identifying each process controller that is driven by natural gas and that does not function as an emergency shutdown device.
(ii) For each process controller affected facility complying with § 60.5390b(a), you must maintain records of the information specified in paragraphs (c)(6)(ii)(A) and (B) of this section, as applicable.
(A) If you are complying with § 60.5390b(a) by routing process controller vapors to a process through a closed vent system, you must report the information specified in paragraphs (c)(6)(ii)(A)( 1) and ( 2) of this section.
( 1) An identification of all the natural gas-driven process controllers in the process controller affected facility for which you collect and route vapors to a process through a closed vent system.
( 2) The records specified in paragraphs (c)(8), (10), and (12) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424b.
(B) If you are complying with § 60.5390b(a) by using a self-contained natural gas-driven process controller, you must report the information specified in paragraphs (c)(6)(ii)(B)( 1) through ( 3) of this section.
( 1) An identification of each process controller complying with § 60.5390b(a) by using a self-contained natural gas-driven process controller;
( 2) Dates of each inspection required under § 60.5416b(b); and
( 3) Each defect or leak identified during each natural gas-driven-self-contained process controller system inspection, and date of repair or date of anticipated repair if repair is delayed.
(iii) For each process controller affected facility complying with the § 60.5390b(b)(1) process controller bleed rate requirements, you must maintain records of the information specified in paragraphs (c)(6)(iii)(A) and (B) of this section.
(A) The identification of process controllers designed and operated to achieve a bleed rate less than or equal to 6 scfh and records of the manufacturer's specifications indicating that the process controller is designed with a natural gas bleed rate of less than or equal to 6 scfh.
(B) Where necessary to meet a functional need, the identification of the process controller and demonstration of why it is necessary to use a process controller with a natural gas bleed rate greater than 6 scfh.
(iv) For each intermittent vent process controller in the affected facility complying with the requirements in paragraphs § 60.5390b(b)(2), you must keep records of the information specified in paragraphs (c)(6)(iv)(A) through (C) of this section.
(A) The identification of each intermittent vent process controller.
(B) Dates and results of the intermittent vent process controller monitoring required by § 60.5390b(b)(2)(ii).
(C) For each instance in which monitoring identifies emissions to the atmosphere from an intermittent vent controller during idle periods, the date of repair or replacement, or the date of anticipated repair or replacement if the repair or replacement is delayed and the date and results of the re-survey after repair or replacement.
(v) For each process controller affected facility complying with § 60.5390b(b)(3), you must maintain the records specified in paragraphs (c)(6)(v)(A) and (B) of this section.
(A) An identification of each process controller for which emissions are routed to a control device.
(B) Records specified in paragraphs (c)(8) and (c)(10) through (13) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424b.
(vi) Records of each change in compliance method, including identification of each natural gas-driven process controller which changes its method of compliance, the new method of compliance, and the date of the change in compliance method.
(vii) Records of each deviation, the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(7) For each storage vessel affected facility, you must maintain the records identified in paragraphs (c)(7)(i) through (vii) of this section.
(i) You must maintain records of the identification and location in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983 of each storage vessel affected facility.
(ii) Records of each methane and VOC emissions determination for each storage vessel affected facility made under § 60.5365b(e) including identification of the model or calculation methodology used to calculate the methane and VOC emission rate.
(iii) For each instance where the storage vessel was not operated in compliance with the requirements specified in § 60.5395b a description of the deviation, the date and time each deviation began, and the duration of the deviation.
(iv) If complying with the emissions reduction standard in § 60.5395b(a)(2), you must maintain the records in paragraphs (c)(7)(iv)(A) through (E) of this section.
(A) If you comply with the emission reduction standard with a control device, the information for each control device in paragraphs (c)(11) and (13) of this section.
(B) Records of the closed vent system inspection as specified paragraph (c)(8) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424b.
(C) Records of the cover inspections as specified in paragraph (c)(9) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (c)(9) of this section, you must provide the information specified in § 60.5424b.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(10) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(12) of this section.
(v) For storage vessels that are skid-mounted or permanently attached to something that is mobile (such as trucks, railcars, barges or ships), records indicating the number of consecutive days that the vessel is located at a site in the crude oil and natural gas source category. If a storage vessel is removed from a site and, within 30 days, is either returned to the site or replaced by another storage vessel at the site to serve the same or similar function, then the entire period since the original storage vessel was first located at the site, including the days when the storage vessel was removed, will be added to the count towards the number of consecutive days.
(vi) Records of the date that each storage vessel affected facility or portion of a storage vessel affected facility is removed from service and returned to service, as applicable.
(vii) Records of the date that liquids from the well following fracturing or refracturing are routed to the storage vessel affected facility; or the date that you comply with paragraph § 60.5395b(a)(2), following a monthly emissions determination which indicates that VOC emissions from your storage vessel affected facility increase to 4 tpy or greater or methane emissions increase to 14 tpy or greater and the increase is not associated with fracturing or refracturing of a well feeding the storage vessel affected facility, and records of the methane and VOC emissions rate and the model or calculation methodology used to calculate the methane and VOC emission rate.
(8) Records of each closed vent system inspection required under § 60.5416b(a)(1) and (2) and (b) for your well, centrifugal compressor, reciprocating compressor, process controller, pump, storage vessel, and process unit equipment affected facility as required in paragraphs (c)(8)(i) through (iv) of this section.
(i) A record of each closed vent system inspection or no identifiable emissions monitoring survey. You must include an identification number for each closed vent system (or other unique identification description selected by you), the date of the inspection, and the method used to conduct the inspection ( i.e., visual, AVO, OGI, Method 21 of appendix A-7 to this part).
(ii) For each defect or emissions detected during inspections required by § 60.5416b(a)(1) and (2) or (b), you must record the location of the defect or emissions; a description of the defect; the maximum concentration reading obtained if using Method 21 of appendix A-7 to this part; the indication of emissions detected by AVO if using AVO; the date of detection; the date of each attempt to repair the emissions or defect; the corrective action taken during each attempt to repair the defect; and the date the repair to correct the defect or emissions is completed.
(iii) If repair of the defect is delayed as described in § 60.5416b(b)(6), you must record the reason for the delay and the date you expect to complete the repair.
(iv) Parts of the closed vent system designated as unsafe to inspect as described in § 60.5416b(b)(7) or difficult to inspect as described in § 60.5416b(b)(8), the reason for the designation, and written plan for inspection of that part of the closed vent system.
(9) A record of each cover inspection required under § 60.5416b(a)(3) for your centrifugal compressor, reciprocating compressor, or storage vessel as required in paragraphs (c)(9)(i) through (iv) of this section.
(i) A record of each cover inspection. You must include an identification number for each cover (or other unique identification description selected by you), the date of the inspection, and the method used to conduct the inspection ( i.e., AVO, OGI, Method 21 of appendix A-7 to this part).
(ii) For each defect detected during the inspection you must record the location of the defect; a description of the defect, the date of detection, the maximum concentration reading obtained if using Method 21 of appendix A-7 to this part; the indication of emissions detected by AVO if using AVO; the date of each attempt to repair the defect; the corrective action taken during each attempt to repair the defect; and the date the repair to correct the defect is completed.
(iii) If repair of the defect is delayed as described in § 60.5416b(b)(6), you must record the reason for the delay and the date you expect to complete the repair.
(iv) Parts of the cover designated as unsafe to inspect as described in § 60.5416b(b)(7) or difficult to inspect as described in § 60.5416b(b)(8), the reason for the designation, and written plan for inspection of that part of the cover.
(10) For each bypass subject to the bypass requirements of § 60.5416b(a)(4), you must maintain a record of the following, as applicable: readings from the flow indicator; each inspection of the seal or closure mechanism; the date and time of each instance the key is checked out; date and time of each instance the alarm is sounded.
(11) Records for each control device used to comply with the emission reduction standard in § 60.5377b(d) or (f) for associated gas wells, § 60.5380b(a)(1) or (9) for centrifugal compressor affected facilities, § 60.5385b(d)(2) for reciprocating compressor affected facilities, § 60.5390b(b)(3) for your process controller affected facility in Alaska, § 60.5393b(b)(3) for your pump affected facility, § 60.5395b(a)(2) for your storage vessel affected facility, § 60.5376b(g) for well affected facility gas well liquids unloading, or § 60.5400b(f) or 60.5401b(e) for your process equipment affected facility, as required in paragraphs (c)(11)(i) through (viii) of this section. If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d), keep records of the information in paragraphs (c)(11)(ix) of this section, in lieu of the records required by paragraphs (c)(11)(i) through (iv) and (vi) through (viii) of this section.
(i) For a control device tested under § 60.5413b(d) which meets the criteria in § 60.5413b(d)(11) and (e), keep records of the information in paragraphs (c)(11)(i)(A) through (E) of this section, in addition to the records in paragraphs (c)(11)(ii) through (ix) of this section, as applicable.
(A) Serial number of purchased device and copy of purchase order.
(B) Location of the affected facility associated with the control device in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983.
(C) Minimum and maximum inlet gas flow rate specified by the manufacturer.
(D) Records of the maintenance and repair log as specified in § 60.5413b(e)(4), for all inspection, repair, and maintenance activities for each control device failing the visible emissions test.
(E) Records of the manufacturer's written operating instructions, procedures, and maintenance schedule to ensure good air pollution control practices for minimizing emissions.
(ii) For all control devices, keep records of the information in paragraphs (c)(11)(ii)(A) through (G) of this section, as applicable.
(A) Make, model, and date of installation of the control device, and identification of the affected facility controlled by the device.
(B) Records of deviations in accordance with § 60.5417b(g)(1) through (7), including a description of the deviation, the date and time the deviation began, the duration of the deviation, and the cause of the deviation.
(C) The monitoring plan required by § 60.5417b(c)(2).
(D) Make and model number of each continuous parameter monitoring system.
(E) Records of minimum and maximum operating parameter values, continuous parameter monitoring system data (including records that the pilot or combustion flame is present at all times), calculated averages of continuous parameter monitoring system data, and results of all compliance calculations.
(F) Records of continuous parameter monitoring system equipment performance checks, system accuracy audits, performance evaluations, or other audit procedures and results of all inspections specified in the monitoring plan in accordance with § 60.5417b(c)(2). Records of calibration gas cylinders, if applicable.
(G) Periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities Records of repairs on the monitoring system.
(iii) For each carbon adsorption system, records of the schedule for carbon replacement as determined by the design analysis requirements of § 60.5413b(c)(2) and (3) and records of each carbon replacement as specified in § 60.5412b(c)(1) and § 60.5415b(f)(1)(viii).
(iv) For enclosed combustion devices and flares, records of visible emissions observations as specified in paragraph (c)(11)(iv)(A) or (B) of this section.
(A) Records of observations with Method 22 of appendix A-7 to this part, including observations required following return to operation from a maintenance or repair activity, which include: company, location, company representative (name of the person performing the observation), sky conditions, process unit (type of control device), clock start time, observation period duration (in minutes and seconds), accumulated emission time (in minutes and seconds), and clock end time. You may create your own form including the above information or use Figure 22-1 in Method 22 of appendix A-7 to this part.
(B) If you monitor visible emissions with a video surveillance camera, location of the camera and distance to emission source, records of the video surveillance output, and documentation that an operator looked at the feed daily, including the date and start time of observation, the length of observation, and length of time visible emissions were present.
(v) For enclosed combustion devices and flares, video of the OGI inspection conducted in accordance with § 60.5415b(f)(1)(x). Records documenting each enclosed combustion device and flare was visibly observed during each inspection conducted under § 60.5397b using AVO in accordance with § 60.5415b(f)(1)(x).
(vi) For enclosed combustion devices and flares, records of each demonstration of the NHV of the inlet gas to the enclosed combustion device or flare conducted in accordance with § 60.5417b(d)(8)(iii). For each re-evaluation of the NHV of the inlet gas, records of process changes and explanation of the conditions that led to the need to re-evaluation the NHV of the inlet gas. For each demonstration, record information on whether the enclosed combustion device or flare has the potential to receive inert gases, and if so, the highest percentage of inert gases that can be sent to the enclosed combustion device or flare and the highest percent of inert gases sent to the enclosed combustion device or flare during the NHV demonstration. Records of periodic sampling conducted under § 60.5417b(d)(8)(iii)(G).
(vii) For enclosed combustion devices and flares, if you use a backpressure regulator valve, the make and model of the valve, date of installation, and record of inlet flow rating. Maintain records of the engineering evaluation and manufacturer specifications that identify the pressure set point corresponding to the minimum inlet gas flow rate, the annual confirmation that the backpressure regulator valve set point is correct and consistent with the engineering evaluation and manufacturer specifications, and the annual confirmation that the backpressure regulator valve fully closes when not in open position.
(viii) For enclosed combustion devices and flares, records of each demonstration required under § 60.5417b(d)(8)(iv).
(ix) If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412b(d), keep records of the information in paragraphs (c)(11)(ix)(A) through (H) of this section, in lieu of the records required by paragraphs (c)(11)(i) through (iv) and (c)(11)(vi) through (viii) of this section.
(A) An identification of the alternative test method used.
(B) Data recorded at the intervals required by the alternative test method.
(C) Monitoring plan required by § 60.5417(i)(2).
(D) Quality assurance and quality control activities conducted in accordance with the alternative test method.
(E) If required by § 60.5412b(d)(4) to conduct visible emissions observations, records required by paragraph (c)(11)(iv) of this section.
(F) If required by § 60.5412b(d)(5) to conduct pilot or combustion flame monitoring, record indicating the presence of a pilot or combustion flame and periods when the pilot or combustion flame is absent.
(G) For each instance where there is a deviation of the control device in accordance with § 60.5417b(i)(6)(i) through (v), the date and time the deviation began, the duration of the deviation in hours, and cause of the deviation.
(H) Any additional information required to be recorded as specified by the Administrator as part of the alternative test method approval under § 60.5412b(d).
(12) For each closed vent system routing to a control device or process, the records of the assessment conducted according to § 60.5411b(c):
(i) A copy of the assessment conducted according to § 60.5411b(c)(1); and
(ii) A copy of the certification according to § 60.5411b(c)(1)(i) and (ii).
(13) A copy of each performance test submitted under paragraphs (b)(12) or (13) of this section.
(14) For the fugitive emissions components affected facility, maintain the records identified in paragraphs (c)(14)(i) through (viii) of this section.
(i) The date of the startup of production or the date of the first day of production after modification for the fugitive emissions components affected facility at a well site and the date of startup or the date of modification for the fugitive emissions components affected facility at a compressor station.
(ii) For the fugitive emissions components affected facility at a well site, you must maintain records specifying what type of well site it is ( i.e., single wellhead only well site, small wellsite, multi-wellhead only well site, or a well site with major production and processing equipment.)
(iii) For the fugitive emissions components affected facility at a well site where you complete the removal of all major production and processing equipment such that the well site contains only one or more wellheads, record the date the well site completes the removal of all major production and processing equipment from the well site, and, if the well site is still producing, record the well ID or separate tank battery ID receiving the production from the well site. If major production and processing equipment is subsequently added back to the well site, record the date that the first piece of major production and processing equipment is added back to the well site.
(iv) The fugitive emissions monitoring plan as required in § 60.5397b(b), (c), and (d).
(v) The records of each monitoring survey as specified in paragraphs (c)(14)(v)(A) through (I) of this section.
(A) Date of the survey.
(B) Beginning and end time of the survey.
(C) Name of operator(s), training, and experience of the operator(s) performing the survey.
(D) Monitoring instrument or method used.
(E) Fugitive emissions component identification when Method 21 of appendix A-7 to this part is used to perform the monitoring survey.
(F) 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.
(G) Any deviations from the monitoring plan or a statement that there were no deviations from the monitoring plan.
(H) Records of calibrations for the instrument used during the monitoring survey.
(I) Documentation of each fugitive emission detected during the monitoring survey, including the information specified in paragraphs (c)(14)(v)(I)( 1) through ( 9) of this section.
( 1) Location of each fugitive emission identified.
( 2) Type of fugitive emissions component, including designation as difficult-to-monitor or unsafe-to-monitor, if applicable.
( 3) If Method 21 of appendix A-7 to this part is used for detection, record the component ID and instrument reading.
( 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.
( 5) The date of first attempt at repair of the fugitive emissions component(s).
( 6) The date of successful repair of the fugitive emissions component, including the resurvey to verify repair and instrument used for the resurvey.
( 7) Identification of each fugitive emission component placed on delay of repair and explanation for each delay of repair.
( 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.
( 9) Date of planned shutdowns that occur while there are any components that have been placed on delay of repair.
(vi) For the fugitive emissions components affected facility complying with an alternative means of emissions limitation under § 60.5399b, you must maintain the records specified by the specific alternative fugitive emissions standard for a period of at least 5 years.
(vii) For well closure activities, you must maintain the information specified in paragraphs (c)(14)(vii)(A) through (G) of this section.
(A) The well closure plan developed in accordance with § 60.5397b(l) and the date the plan was submitted.
(B) The notification of the intent to close the well site and the date the notification was submitted.
(C) The date of the cessation of production from all wells at the well site.
(D) The date you began well closure activities at the well site.
(E) Each status report for the well closure activities reported in paragraph (b)(9)(iv)(A) of this section.
(F) Each OGI survey reported in paragraph (b)(9)(iv)(B) of this section including the date, the monitoring instrument used, and the results of the survey or resurvey.
(G) The final OGI survey video demonstrating the closure of all wells at the site. The video must include the date that the video was taken and must identify the well site location by latitude and longitude.
(viii) If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraphs (c)(14)(iv) and (v) of this section, you must maintain the records specified in § 60.5424b.
(15) For each pump affected facility, you must maintain the records identified in paragraphs (c)(15)(i) through (ix) of this section.
(i) Identification of each pump that is driven by natural gas and that is in operation 90 days or more per calendar year.
(ii) If you are complying with § 60.5393b(a) or (b)(1) by routing pump vapors to a process through a closed vent system, identification of all the pumps in the pump affected facility for which you collect and route vapors to a process through a closed vent system and the records specified in paragraphs (c)(8), (10), and (12) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424b.
(iii) If you are complying with § 60.5393b(b)(1) by routing pump vapors to control device achieving a 95.0 percent reduction in methane and VOC emissions, you must keep the records specified in paragraphs (c)(8) and (10) through (c)(13) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398b, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424b.
(iv) If you are complying with § 60.5393b(b)(5) by routing pump vapors to control device achieving less than a 95.0 percent reduction in methane and VOC emissions, you must maintain records of the certification that there is a control device on site but it does not achieve a 95.0 percent emissions reduction and a record of the design evaluation or manufacturer's specifications which indicate the percentage reduction the control device is designed to achieve.
(v) If you have less than three natural gas-driven diaphragm pumps in the pump affected facility, and you do not have a vapor recovery unit or control device installed on site by the compliance date, you must retain a record of your certification required under § 60.5393b(b)(6), certifying that there is no vapor recovery unit or control device on site. If you subsequently install a control device or vapor recovery unit, you must maintain the records required under paragraph (c)(15)(ii) and paragraph (c)(15)(iii) or (iv) of this section, as applicable.
(vi) If you determine, through an engineering assessment, that it is technically infeasible to route the pump affected facility emissions to a process or control device, you must retain records of your demonstration and certification that it is technically infeasible as required under § 60.5393b(b)(5).
(vii) If the pump is routed to a control device that is subsequently removed from the location or is no longer available such that there is no option to route to a control device, you are required to retain records of this change and the records required under paragraph (c)(15)(vi) of this section.
(viii) Records of each change in compliance method, including identification of each natural gas-driven pump which changes its method of compliance, the new method of compliance, and the date of the change in compliance method.
(ix) Records of each deviation, the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(d) Electronic reporting. If you are required to submit notifications or reports following the procedure specified in this paragraph (d), 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 paragraphs (d)(1) and (2) of this section. 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 (d).
* * * * *31. Amend § 60.5421b by:
a. Revising and republishing the introductory text and paragraph (b) introductory text; and
b. Redesignating (b)(11)(vi) introductory text as (b)(11)(iv) introductory text and revising it.
The revisions read as follows:
What are my additional recordkeeping requirements for process unit equipment affected facilities?You must maintain a record of each equipment leak monitoring inspection and each leak identified under § 60.5400b and § 60.5401b as specified in paragraphs (b)(1) through (17) of this section. The record must be maintained either onsite or at the nearest local field office for at least 5 years. Any records required to be maintained 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.
* * * * *(b) You must maintain the monitoring inspection records specified in paragraphs (b)(1) through (17) of this section.
* * * * *(11) * * *
(iv) The date of successful repair of the leak and the method of monitoring used to confirm the repair, as specified in paragraph (b)(11)(iv)(A) through (C) of this section.
* * * * *32. Amend § 60.5424b by revising paragraph (e)(6) to read as follows:
What are my additional recordkeeping and reporting requirements if I comply with the alternative GHG and VOC standards for fugitive emissions components affected facilities and covers and closed vent systems?* * * * *(e) * * *
(6) Each rolling 12-month average operational downtime for the system, calculated in accordance with § 60.5398b(c)(1)(iv)(D).
* * * * *33. Amend § 60.5430b by revising the definitions for No identifiable emissions and Storage vessel to read as follows:
What definitions apply to this subpart?* * * * *No identifiable emissions means, for the purposes of covers, closed vent systems, and self-contained natural gas-driven process controllers and as determined according to the provisions of § 60.5416b, that no emissions are detected by AVO means when inspections are conducted by AVO; no emissions are imaged with an OGI camera when inspections are conducted with OGI; and equipment is operating with an instrument reading of less than 500 ppmv above background, as determined by Method 21 of appendix A-7 to this part when inspections are conducted with Method 21.
* * * * *Storage vessel means a tank or other vessel that contains an accumulation of crude oil, condensate, intermediate hydrocarbon liquids, or produced water, and that is constructed primarily of nonearthen materials (such as wood, concrete, steel, fiberglass, or plastic) which provide structural support. A well completion vessel that receives recovered liquids from a well after startup of production following flowback for a period which exceeds 60 days is considered a storage vessel under this subpart. A tank or other vessel shall not be considered a storage vessel if it has been removed from service in accordance with the requirements of § 60.5395b(c)(1) until such time as such tank or other vessel has been returned to service. For the purposes of this subpart, the following are not considered storage vessels:
(1) Vessels that are skid-mounted or permanently attached to something that is mobile (such as trucks, railcars, barges or ships), and are intended to be located at a site for less than 180 consecutive days. If you do not keep or are not able to produce records, as required by § 60.5420b(c)(7)(v), showing that the vessel has been located at a site for less than 180 consecutive days, the vessel described herein is considered to be a storage vessel from the date the original vessel was first located at the site. This exclusion does not apply to a well completion vessel as described above.
(2) Process vessels such as surge control vessels, bottoms receivers or knockout vessels.
(3) Pressure vessels designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere.
* * * * *34. Revise table 3 to subpart OOOOb of part 60 to read as follows:
Table 3 to Subpart OOOO b of Part 60—Required Minimum Initial SO 2 Emission Reduction Efficiency (Z i )
H 2 S content of acid gas (Y), % Sulfur feed rate (X), LT/D 2.0 ≤ X ≤ 5.0 5.0 < X ≤ 15.0 15.0 < X ≤ 300.0 X > 300.0 Y ≥ 50 79.0 88.51X0.0101 Y0.0125 or 99.9, whichever is smaller. 20 ≤ Y < 50 79.0 88.51X0.0101 Y0.0125 or 97.9, whichever is smaller 97.9 10 ≤ Y < 20 79.0 88.51X0.0101 Y0.0125 or 93.5, whichever is smaller 93.5 93.5 Y < 10 79.0 79.0 79.0 79.0 35. Revise table 4 to subpart OOOO b of part 60 to read as follows:
Table 4 to Subpart OOOO b of Part 60—Required Minimum SO 2 Emission Reduction Efficiency (Z c )
H 2 S content of acid gas (Y), % Sulfur feed rate (X), LT/D 2.0 ≤ X ≤ 5.0 5.0 < X ≤ 15.0 15.0 < X ≤ 300.0 X > 300.0 Y ≥ 50 74.0 85.35X0.0144 Y0.0128 or 99.9, whichever is smaller. 20 ≤ Y < 50 74.0 85.35X0.0144 Y0.0128 or 97.5, whichever is smaller 97.5 10 ≤ Y < 20 74.0 85.35X0.0144 Y0.0128 or 90.8, whichever is smaller 90.8 90.8 Y < 10 74.0 74.0 74.0 74.0 36. Amend table 5 to subpart OOOOb of part 60 by revising the entry for “§ 60.8” to read as follows:
Table 5 to Subpart OOOO b of Part 60—Applicability of General Provisions to Subpart OOOO b
General provisions citation Subject of citation Applies to subpart? Explanation * * * * * * * § 60.8 Performance tests 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, wells, reciprocating compressors, process controllers, and pumps, as applicable, except that performance testing is not required for a control device used solely on pump(s). * * * * * * * Subpart OOOOc —Emissions Guidelines for Greenhouse Gas Emissions from Existing Crude Oil and Natural Gas Facilities
37. Amend § 60.5370c by revising paragraph (b) to read as follows:
What compliance schedule must I include in my state or Tribal plan?* * * * *(b) The plan must include legally enforceable increments of progress to achieve compliance for each designated facility or category of facilities, as specified in §§ 60.5379c through 60.5381c.
38. Amend § 60.5374c by revising paragraph (b) to read as follows:
Does this subpart directly affect designated facility owners and operators in my state?* * * * *(b) If you do not submit a plan to implement and enforce the guidelines contained in this subpart by the date 24 months after promulgation of this subpart, or if EPA disapproves your plan, the EPA will implement and enforce a Federal plan, as provided in § 60.5368c of this subpart, to ensure that each designated facility within your state that commenced construction, modification or reconstruction on or before December 6, 2022, reaches compliance with all the provisions of this subpart by the dates specified in § 60.5360c of this subpart.
39. Amend § 60.5375c by revising paragraph (a)(3) to read as follows:
What designated facilities must I address in my state or Tribal plan?(a) * * *
(3) Designated facilities not exempt under § 60.14(e).
* * * * *40. Amend § 60.5386c by revising paragraph (e)(2)(i)(C) to read as follows:
Am I subject to this subpart?* * * * *(e) * * *
(2) * * *
(i) * * *
(C) Established parametric limits for the production and/or operational limit(s) in paragraph (e)(2)(i)(A), and where a control device is used to achieve an operational limit, an initial compliance demonstration ( i.e., performance test) for the control device that establishes the parametric limits;
* * * * *41. Amend § 60.5388c by:
a. Revising paragraphs (a)(1) and (2);
b. Removing paragraph (a)(3);
c. Redesignating paragraph (a)(4) as paragraph (a)(3); and
d. Revising paragraph (b)(1)(v).
The revisions read as follows:
What standards apply to super-emitter events?* * * * *(a) * * *
(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 subject to the regulation under this subpart, report this result to the EPA under paragraph (b) of this section. Your super-emitter event investigation is deemed complete under this subpart.
(2) If you own or operate an oil and natural gas facility within 50 meters from the latitude and longitude provided in the notification, and there is a designated facility or associated equipment subject to this subpart onsite, you must investigate to determine the source of the super-emitter event in accordance with this paragraph (a) and report the results in accordance with paragraph (b) of this section. The investigation required by this paragraph (a)(2) of this section may include but is not limited to the actions specified below in paragraphs (a)(2)(i) through (v) of this section.
(i) Review any maintenance activities ( e.g., liquids unloading) or process activities from the designated 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.
(ii) Review all monitoring data from control devices ( e.g., flares) from the designated 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 to identify 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.
(iii) If you conducted a fugitive emissions survey or periodic screening event in accordance with § 60.5397c or § 60.5398c(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.
(iv) If you use conduct continuous monitoring with advanced methane detection technology in accordance with § 60.5398c(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.
(v) Screen the entire well site, centralized production facility, or compressor station with OGI, Method 21 of appendix A-7 to this part, or an alternative test method(s) approved per § 60.5398c(d), to determine if a super-emitter event is present
* * * * *(b) * * *
(1) * * *
(v) 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 paragraphs (a)(2)(i) through (v) of this section have been conducted for all designated facilities and associated equipment subject to regulation under this subpart that are at this oil and natural gas facility, and you have determined that the designated 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 paragraphs (b)(1)(vi) through (viii) of this section.
* * * * *42. Amend § 60.5390c by:
a. Revising and republishing paragraph (a)(1) introductory text; and
b. Redesignating paragraphs (a)(1)(A) and (B) as paragraphs (a)(1)(i) and (ii).
The revision reads as follows:
What GHG standards apply to gas well liquids unloading operations at well designated facilities?(a) * * *
(1) If a gas well liquids unloading operation technology or technique employed does not result in venting of methane emissions to the atmosphere, you must comply with the requirements specified in paragraphs (a)(1)(i) and (ii) and (d) and (e) of this section. If an unplanned venting event occurs, you must meet the requirements specified in paragraphs (c) through (f) of this section.
* * * * *43. Amend § 60.5391c by revising and republishing paragraphs (b) through (e) and (g) and (h) to read as follows:
What GHG standards apply to associated gas wells at well designated facilities?* * * * *(b) If you meet one of the conditions in paragraphs (b)(1) or (2) of this section, you may route the associated gas to a control device that reduces methane emissions by at least 95.0 percent instead of complying with paragraph (a) of this section. The associated gas must be routed through a closed vent system that meets the requirements of § 60.5411c(a) and (c) and the control device must meet the conditions specified in § 60.5412c(a), (b), and (c).
(1) If the annual methane contained in the associated gas from your oil well is 40 tons per year or less at the initial compliance date, determined in accordance with paragraph (e) of this section.
(2) If you demonstrate and certify that it is not feasible to comply with paragraph (a)(1), (2), (3), and (4) of this section due to technical reasons by providing a detailed analysis documenting and certifying the technical reasons for this infeasibility in accordance with paragraphs (b)(2)(i) through (iv) of this section.
(i) In order to demonstrate that it is not feasible to comply with paragraph (a)(1), (2), (3), and (4) of this section, you must provide a detailed analysis documenting and certifying the technical reasons for this infeasibility. The demonstration must address the technical infeasibility for all options identified in (a)(1), (2), (3), and (4) of this section. Documentation of these demonstrations must be maintained in accordance with § 60.5420c(c)(2)(iv).
(ii) This demonstration must be certified by a professional engineer or another qualified individual with expertise in the uses of associated gas. The following certification, signed and dated by the qualified professional engineer or other qualified individual shall state: “I certify that the assessment of technical and safety infeasibility was prepared under my direction or supervision. I further certify that the assessment was conducted, and this report was prepared pursuant to the requirements of § 60.5391c(b)(2). Based on my professional knowledge and experience, and inquiry of personnel involved in the assessment, the certification submitted herein is true, accurate, and complete.”
(iii) This demonstration and certification are valid for no more than 12 months. You must re-analyze the feasibility of complying with paragraphs (a)(1), (2), (3), and (4) of this section and finalize a new demonstration and certification each year.
(iv) Documentation of these demonstrations, along with the certifications, must be maintained in accordance with § 60.5420c(c)(2)(iv) and submitted in annual reports in accordance with § 60.5420c(b)(3).
(c) If you are complying with paragraph (a) of this section, you may temporarily route the associated gas to a flare or control device in the situations and for the durations identified in paragraphs (c)(1), (2), (3), or (4) of this section. The associated gas must be routed through a closed vent system that meets the requirements of § 60.5411c(a) and (c) and the control device must meet the conditions specified in § 60.5412c. If you are routing to a flare, you must demonstrate that the § 60.18 flare requirements are met during the period when the associated gas is routed to the flare. Records must be kept of all temporary flaring instances in accordance with § 60.5420c(c)(2) and reported in the annual report in accordance with § 60.5420c(b)(3).
(1) For equal to or less than 24 hours during a deviation caused by malfunction causing the need to flare.
(2) For equal to or less than 24 hours during repair, maintenance including blow downs, a bradenhead test, a packer leakage test, a production test, or commissioning.
(3) For wells complying with paragraph (a)(1) of this section, for the duration of a temporary interruption in service from the gathering or pipeline system, or 30 days, whichever is less.
(4) For 72 hours from the time that the associated gas does not meet pipeline specifications, or until the associated gas meets pipeline specifications, whichever is less.
(d) If you are complying with paragraph (a), (b), or (c) of this section, you may vent the associated gas in the situations and for the durations identified in paragraphs (d)(1), (2), or (3) of this section. Records must be kept of all venting instances in accordance with § 60.5420c(c)(2) and reported in the annual report in accordance with § 60.5420c(b)(3).
(1) For up to 12 hours to protect the safety of personnel.
(2) For up to 30 minutes during bradenhead monitoring.
(3) For up to 30 minutes during a packer leakage test.
(e) Calculate the methane content in associated gas as specified in paragraph (e)(1) of this section and comply with paragraphs (e)(2) and (e)(3) of this section.
(1) Calculate the methane content in associated gas from your oil well using the following equation
Equation 1 to Paragraph (e)(1)
Where:
AGmethane = Amount of methane in associated gas from the oil well, tons methane per year
GOR = Gas to oil ratio for the well in standard cubic feet of gas per barrel of oil; oil here refers to hydrocarbon liquids produced of all API gravities. GOR is to be determined for the well using available data, an appropriate standard method published by a consensus-based standards organization which include, but are not limited to, the following: ASTM International, the American National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical Engineers (ASME), the American Petroleum Institute (API), and the North American Energy Standards Board (NAESB), or in industry standard practice.
V = Volume of oil produced in the calendar year preceding the initial compliance date, in barrels per year.
Mmethane = mole fraction of methane in the associated gas.
0.0192 = density of methane gas at 60 °F and 14.7 psia in kilograms per cubic foot
907.2 = conversion of kilograms to tons, kilograms per ton
(2) You must maintain records of the calculation of the methane in associated gas from your oil well results in accordance with § 60.5420c(c)(2), and submit the information, as well as the background information, in the next annual report in accordance with § 60.5420c(b)(3).
(3) If a process change occurs that could increase the methane content in the associated gas, you must recalculate the methane content in accordance with paragraph (e)(1) of this section.
* * * * *(g) You must demonstrate continuous compliance with the standards that apply to associated gas wells at well designated facilities as required by § 60.5415c(b).
(h) You must perform the recordkeeping and reporting as required by § 60.5420c(b)(1), (3), and (10) through (12), as applicable, and § 60.5420c(c)(2) and (7) and (9) through (12), as applicable.
44. Amend § 60.5392c by revising paragraph (a) introductory text to read as follows:
What GHG standards apply to centrifugal compressor designated facilities?* * * * *(a) Each centrifugal compressor designated facility that is a wet or dry seal centrifugal compressor must comply with the GHG standards, using volumetric flow rate as a surrogate, as specified in paragraphs (a)(1) and (2) of this section. Alternatively, you have the option of complying with the GHG standards for your wet seal and dry seal centrifugal compressor by meeting the requirements specified in paragraph (a)(3), and either paragraph (a)(4) or (5) of this section.
* * * * *45. Amend § 60.5393c by revising and republishing paragraph (g) to read as follows:
What GHG standards apply to reciprocating compressor designated facilities?* * * * *(g) You must perform the reporting requirements as specified in § 60.5420c(b)(1) and (5) and (10) through (12), as applicable; and the recordkeeping requirements as specified in § 60.5420c(c)(4) and (7) through (12), as applicable.
46. Amend § 60.5394c by revising paragraph (b)(3) to read as follows:
What GHG standards apply to process controller designated facilities?* * * * *(b) * * *
(3) You must reduce methane emissions from all controllers in the process controller designated facility by 95.0 percent. You must route emissions to a control device through a closed vent system that meets the conditions specified in § 60.5412c.
* * * * *47. Amend § 60.5395c by revising paragraphs (b)(6)(ii) and (b)(7)(iii) to read as follows:
What GHG standards apply to pump designated facilities?* * * * *(b) * * *
(6) * * *
(ii) You must maintain the records in § 60.5420c(c)(14)(ii) and (v), as applicable. You are no longer required to maintain the records in § 60.5420c(c)(14)(v) certifying that there is no vapor recovery unit or control device on site.
(7) * * *
(iii) The following certification, signed and dated by the qualified professional engineer or in-house engineer, must state: “I certify that the assessment of technical infeasibility was prepared under my direction or supervision. I further certify that the assessment was conducted and this report was prepared pursuant to the requirements of § 60.5395c(b)(7)(ii). Based on my professional knowledge and experience, and inquiry of personnel involved in the assessment, the certification submitted herein is true, accurate, and complete.”
* * * * *48. Amend § 60.5396c by revising paragraphs (a)(3) introductory text, (c)(1)(ii), and (c)(4) to read as follows:
What GHG standards apply to storage vessel designated facilities?* * * * *(a) * * *
(3) Maintain the uncontrolled actual methane emissions from the storage vessel designated facility at less than 14 tpy without considering control in accordance with paragraphs (a)(3)(i) and (ii) of this section. Prior to using the uncontrolled actual methane emission rates for compliance purposes, you must demonstrate that the uncontrolled actual methane emissions have remained less than 14 tpy as determined monthly for 12 consecutive months. After such demonstration, you must determine the uncontrolled actual rolling 12-month determination methane emissions rates each month. The uncontrolled actual methane emissions must be calculated using a generally accepted model or calculation methodology which account for flashing, working, and breathing losses, and the calculations must be based on the actual average throughput, temperature, and separator pressure for the month. You may no longer comply with this paragraph and must instead comply with paragraph (a)(2) of this section if your storage vessel designated facility meets the conditions specified in paragraphs (a)(3)(i) or (ii) of this section.
* * * * *(c) * * *
(1) * * *
(ii) You must submit a notification as required in § 60.5420c(b)(7)(vii) in your next annual report, identifying each storage vessel designated facility removed from service during the reporting period and the date of its removal from service.
* * * * *(4) For each storage vessel designated facility or portion of a storage vessel designated facility returned to service during the reporting period, you must submit a notification in your next annual report as required in § 60.5420c(b)(7)(viii), identifying each storage vessel designated facility or portion of a storage vessel designated facility and the date of its return to service.
* * * * *49. Amend § 60.5398c by revising and republishing paragraphs (b) and (c)(5)(ii) to read as follows:
What alternative GHG standards apply to fugitive emissions components designated facilities and what inspection and monitoring requirements apply to covers and closed vent systems when using an alternative technology?* * * * *(b) Periodic screening. You may choose to demonstrate compliance for your fugitive emissions components designated facility and compliance with continuous inspection and monitoring requirements for your covers and closed vent systems through periodic screenings using any methane measurement technology approved in accordance with § 60.5398b(d). If you choose to demonstrate compliance using periodic screenings, you must comply with the requirements in paragraphs (b)(1) through (5) of this section and comply with the recordkeeping and reporting requirements in § 60.5424c.
(1) You must use one or more alternative test method(s) approved per § 60.5398b(d) to conduct periodic screenings.
(i) The required frequencies for conducting periodic screenings are listed in tables 2 and 3 to this subpart. You must choose the appropriate frequency for conducting periodic screenings based on the minimum aggregate detection threshold of the method used to conduct the periodic screenings. You must also use tables 2 and 3 to this subpart to determine whether you must conduct an annual fugitive emissions survey using OGI, except as provided in paragraph (b)(1)(ii) of this section.
(ii) Use of table 2 or 3 to this subpart is based on the required frequency for conducting monitoring surveys in § 60.5397c(g)(1)(i) through (v).
(iii) You may replace one or more individual periodic screening events required by table 2 or 3 to this subpart with an OGI survey. The OGI survey must be conducted according to the requirements outlined in § 60.5397c.
(iv) If you use multiple methods to conduct periodic screenings, you must conduct all periodic screenings, regardless of the method used for the individual periodic screening event, at the frequency required for the alternative test method with the highest aggregate detection threshold ( e.g., if you use methods with aggregate detection thresholds of 15 kg/hr, your periodic screenings must be conducted monthly). You must also conduct an annual OGI survey if an annual OGI survey is required for the alternative test method with the highest aggregate detection threshold.
(2) You must develop a monitoring plan that covers the collection of fugitive emissions components, covers, and closed vent systems at each site where you will use periodic screenings to demonstrate compliance. You may develop a site-specific monitoring plan, or you may include multiple sites that you own or operate in one plan. At a minimum, the monitoring plan must contain the information specified in paragraphs (b)(2)(i) through (ix) of this section.
(i) Identification of each site that will be monitored through periodic screening, including latitude and longitude coordinates of the site in decimal degrees to an accuracy and precision of five decimals of a degree using the North American Datum of 1983.
(ii) Identification of the alternative test method(s) approved per § 60.5398b(d) that will be used for periodic screenings and the spatial resolution ( i.e., component-level, area-level, or facility-level) of the technology used for each method.
(iii) Identification of and contact information for the entities that will be performing the periodic screenings.
(iv) Required frequency for conducting periodic screenings, based on the criteria outlined in paragraph (b)(1) of this section.
(v) If you are required to conduct an annual OGI survey by paragraph (b)(1)(i) or (iii) of this section or you choose to replace any individual screening event with an OGI survey, your monitoring plan must also include the information required by § 60.5397c(b).
(vi) Procedures for conducting monitoring surveys required by paragraphs (b)(5)(ii)(A), (b)(5)(iii)(A), and (b)(5)(iv)(A) of this section. At a minimum, your monitoring plan must include the information required by § 60.5397c(c)(2), (3), (7), and (8) and § 60.5397c(d), as applicable. The provisions of § 60.5397c(d)(3) do not apply for purposes of conducting monitoring surveys required by paragraphs (b)(5)(ii) through (iv) of this section.
(vii) Procedures and timeframes for identifying and repairing fugitive emissions components, covers, and closed vent systems from which emissions are detected.
(viii) Procedures and timeframes for verifying repairs for fugitive emissions components, covers, and closed vent systems.
(ix) Records that will be kept and the length of time records will be kept.
(3) You must conduct the initial screening of your site according to the timeframes specified in (b)(3)(i) and (ii) of this section.
(i) Within 90 days of the effective date of your state or Tribal plan for each fugitive emissions components designated facility and storage vessel designated facility located at a well site.
(ii) No later than the final date by which the next monitoring survey required by § 60.5397c(g)(1)(i) through (v) would have been required to be conducted if you were previously complying with the requirements in § 60.5397c and § 60.5416c.
(4) If you are required to conduct an annual OGI survey by paragraph (b)(1)(i) or (iii) of this section, you must conduct OGI surveys according to the schedule in paragraphs (b)(4)(i) through (iv) of this section.
(i) You must conduct the initial OGI survey no later than 12 calendar months after conducting the initial screening survey in paragraph (b)(3) of this section.
(ii) Each subsequent OGI survey must be conducted no later than 12 calendar months after the previous OGI survey was conducted. Each identified source of fugitive emissions during the OGI survey shall be repaired in accordance with § 60.5397c(h).
(iii) If you replace a periodic screening event with an OGI survey or you are required to conduct a monitoring survey in accordance with paragraph (b)(5)(ii)(A) of this section prior to the date that your next OGI survey under paragraph (b)(4)(ii) of this section is due, the OGI survey conducted in lieu of the periodic screening event or the monitoring survey under paragraph (b)(5)(ii)(A) of this section can be used to fulfill the requirements of paragraph (b)(4)(ii) of this section. The next OGI survey is required to be conducted no later than 12 calendar months after the date of the survey conducted under paragraph (b)(1)(iv) or (b)(5)(ii)(A) of this section.
(iv) You cannot use a monitoring survey conducted under paragraph (b)(5)(iii)(A) or (b)(5)(iv)(A) of this section to fulfill the requirements of paragraph (b)(4)(ii) of this section unless the monitoring survey included all fugitive emission components at the site.
(5) You must investigate confirmed detections of emissions from periodic screening events and repair each identified source of emissions in accordance with paragraphs (b)(5)(i) through (vi) of this section.
(i) You must receive the results of the periodic screening no later than 5 calendar days after the screening event occurs.
(ii) If you use an alternative test method with a facility-level spatial resolution to conduct a periodic screening event and the results of the periodic screening event indicate a confirmed detection of emissions from a designated facility, you must take the actions listed in paragraphs (b)(5)(ii)(A) through (C) of this section.
(A) You must conduct a monitoring survey of all the fugitive emissions components in a designated facility using either OGI or EPA Method 21 to appendix A-7 of this part. You must follow the procedures in your monitoring plan when conducting the survey.
(B) You must inspect all covers and closed vent system(s) with OGI or Method 21 of appendix A-7 to this part in accordance with the requirements in § 60.5416c(b)(1) through (4), as applicable.
(C) You must conduct a visual inspection of all covers and closed vent systems to identify if there are any defects, as defined in § 60.5416c(a)(1)(ii), § 60.5416c(a)(2)(iii), or § 60.5416c(a)(3)(i), as applicable.
(iii) If you use an alternative test method with an area-level spatial resolution to conduct a periodic screening event and the results of the periodic screening event indicate a confirmed detection of emissions from a designated facility, you must take the actions listed in paragraphs (b)(5)(iii)(A) and (B) of this section, as applicable.
(A) You must conduct a monitoring survey of all the fugitive emissions components located within a 4-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of this part. You must follow the procedures in your monitoring plan when conducting the survey.
(B) If the confirmed detection occurred in the portion of a site that contains a storage vessel or a closed vent system, you must inspect all covers and all closed vent systems that are connected to all storage vessels and closed vent systems that are within a 2-meter radius of the location of the periodic screening's confirmed detection ( i.e., you must inspect the whole system that is connected to the portion of the system in the radius of the detected event, not just the portion of the system that falls within the radius of the detected event).
( 1) You must inspect the cover(s) and closed vent system(s) with OGI or Method 21 of appendix A-7 to this part in accordance with the requirements in § 60.5416c(b)(1) through (4), as applicable.
( 2) You must conduct a visual inspection of the closed vent system(s) and cover(s) to identify if there are any defects, as defined in § 60.5416c(a)(1)(ii), § 60.5416c(a)(2)(iii), or § 60.5416c(a)(3)(i), as applicable.
(iv) If you use an alternative test method with a component-level spatial resolution to conduct a periodic screening event and the results of the periodic screening event indicate a confirmed detection of emissions from a designated facility, you must take the actions listed in paragraphs (b)(5)(iv)(A) and (B) of this section, as applicable.
(A) You must conduct a monitoring survey of all the fugitive emissions components located within a 1-meter radius of the location of the periodic screening's confirmed detection using either OGI or EPA Method 21 to appendix A-7 of this part. You must follow the procedures in your monitoring plan when conducting the survey.
(B) If the confirmed detection occurred in the portion of a site that contains a storage vessel or a closed vent system, you must inspect all covers and all closed vent systems that are connected to all storage vessels and closed vent systems that are within a 0.5-meter radius of the location of the periodic screening's confirmed detection ( i.e., you must inspect the whole system that is connected to the portion of the system in the radius of the detected event, not just the portion of the system that falls within the radius of the detected event).
( 1) You must inspect the cover(s) and closed vent system(s) with OGI or Method 21 of appendix A-7 to this part in accordance with the requirements in § 60.5416c(b)(1) through (4), as applicable.
( 2) You must conduct a visual inspection of the closed vent system(s) and cover(s) to identify if there are any defects, as defined in § 60.5416c(a)(1)(ii), § 60.5416c(a)(2)(iii), or § 60.5416c(a)(3)(i), as applicable.
(v) You must repair all sources of fugitive emissions in accordance with § 60.5397c(h) and all emissions or defects of covers and closed vent systems in accordance with § 60.5416c(b)(4), except as specified in this paragraph (b)(5)(v). Except as allowed by §§ 60.5397c(h)(3) and 60.5416c(b)(5), all repairs must be completed, including the resurvey verifying the repair, within 30 days of receiving the results of the periodic screening in paragraph (b)(5)(i) of this section.
(vi) If the results of the periodic screening event in paragraph (b)(5)(i) of this section indicate a confirmed detection at a designated facility, and the ground-based monitoring survey and inspections required by paragraphs (b)(5)(ii) through (iv) of this section demonstrate the confirmed detection was caused by a failure of a control device used to demonstrate continuous compliance under this subpart, you must initiate an investigative analysis to determine the underlying primary and other contributing cause(s) of such failure within 24 hours of receiving the results of the monitoring survey and/or inspection. As part of the investigation, you must determine if the control device is operating in compliance with the applicable requirements of §§ 60.5415c and 60.5417c, and if not, what actions are necessary to bring the control device into compliance with those requirements as soon as possible and prevent future failures of the control device from the same underlying cause(s).
(vii) If the results of the inspections required in paragraphs (b)(5)(ii) through (iv) of this section indicate that there is an emission or defect in your cover or closed vent system, you must perform an investigative analysis to determine the underlying primary and other contributing cause(s) of emissions from your cover or closed vent system within 5 days of completing the inspection required by paragraphs (b)(5)(ii) through (iv) of this section. The investigative analysis must include a determination as to whether the system was operated outside of the engineering design analysis and whether updates are necessary for the cover or closed vent system to prevent future emissions from the cover and closed vent system.
(6) You must maintain the records as specified in § 60.5420c(c)(3) through (c)(6), (c)(13) and (c)(14) and § 60.5424c(c).
(7) You must submit reports as specified in § 60.5424c.
(c) * * *
(5) * * *
(ii) Verify control devices ( e.g., flares) on all affected sources are operating in compliance with the applicable requirements of §§ 60.5415c and 60.5417c. You must ensure that all control devices are operating in compliance with the applicable regulations prior to beginning the period in paragraph (c)(5)(iii) of this section. Verify that all other methane emission sources ( e.g., reciprocating engines) located at the site are operating consistent with any applicable regulations. You must ensure that these sources are operating in compliance with the applicable regulations prior to beginning the period in paragraph (c)(5)(iii) of this section.
* * * * *50. Amend § 60.5400c by revising paragraphs (a)(1), (k), and (l) to read as follows:
What GHG standards apply to process unit equipment designated facilities?* * * * *(a) * * *
(1) Each piece of equipment is presumed to have the potential to emit methane unless an owner or operator demonstrates that the piece of equipment does not have the potential to emit methane. For a piece of equipment to be considered not to have the potential to emit methane, the methane content of a gaseous stream must be below detection limits using Method 18 of appendix A-6 of this part. Alternatively, if the piece of equipment is in wet gas service, you may choose to determine the methane content of the stream is below the detection limit of the methods described in ASTM E168-16(R2023), E169-16(R2022), or E260-96 (all incorporated by reference, see § 60.17).
* * * * *(k) Reporting. You must perform the reporting requirements as specified in § 60.5420c(b)(1) and (10) through (12), as applicable, and § 60.5422c.
(l) Recordkeeping. You must perform the recordkeeping requirements as specified in § 60.5420c(c)(7) and (9) through (12), as applicable, and § 60.5421c.
51. Amend § 60.5401c by revising and republishing paragraphs (a) introductory text, (b), (c)(5), (f), (l), and (m) to read as follows:
What are the alternative GHG standards for process unit equipment designated facilities?* * * * *(a) General standards. You must comply with the requirements in paragraph (b) of this section for each pump in light liquid service. You must comply with the requirements of paragraph (c) of this section for each pressure relief device in gas/vapor service. You must comply with the requirements in paragraph (d) of this section for each open-ended valve or line. You must comply with the requirements in paragraph (e) of this section for each closed vent system and control device used to comply with equipment leak provisions in this section. You must comply with paragraph (f) of this section for each valve in gas/vapor or light liquid service. You must comply with paragraph (g) of this section for each pump, valve, and connector in heavy liquid service and pressure relief device in light liquid or heavy liquid service. You must comply with paragraph (h) of this section for each connector in gas/vapor and light liquid service. You must make repairs as specified in paragraph (i) of this section. You must demonstrate initial compliance with the standards as specified in paragraph (j) of this section. You must demonstrate continuous compliance with the standards as specified in paragraph (k) of this section. You must perform the reporting requirements as specified in paragraph (l) of this section. You must perform the recordkeeping requirements as required in paragraph (m) of this section.
* * * * *(b) Pumps in light liquid service. You must monitor each pump in light liquid service monthly to detect leaks by the methods specified in § 60.5406c, except as provided in paragraphs (b)(2) through (6) of this section. A leak is defined as an instrument reading of 2,000 ppmv or greater. A pump that begins operation in light liquid service after the initial startup date for the process unit must be monitored for the first time within 30 days after the end of its startup period, except for a pump that replaces a leaking pump and except as provided in paragraphs (b)(2) through (6) of this section.
(1) In addition to the requirements in paragraph (b) of this section, you must conduct weekly visual inspections of all pumps in light liquid service for indications of liquids dripping from the pump seal. If there are indications of liquids dripping from the pump seal, you must follow the procedure specified in either paragraph (b)(1)(i) or (ii) of this section.
(i) Monitor the pump within 5 days using the methods specified in § 60.5406c. A leak is defined as an instrument reading of 2,000 ppmv or greater.
(ii) Designate the visual indications of liquids dripping as a leak, and repair the leak as specified in paragraph (i) of this section.
(2) Each pump equipped with a dual mechanical seal system that includes a barrier fluid system is exempt from the requirements in paragraph (b) of this section, provided the requirements specified in paragraphs (b)(2)(i) through (v) of this section are met.
(i) Each dual mechanical seal system meets the requirements of paragraphs (b)(2)(i)(A), (B), or (C) of this section.
(A) Operated with the barrier fluid at a pressure that is at all times greater than the pump stuffing box pressure; or
(B) Equipped with a barrier fluid degassing reservoir that is routed to a process or fuel gas system or connected by a closed vent system to a control device that complies with the requirements of paragraph (e) of this section; or
(C) Equipped with a system that purges the barrier fluid into a process stream with zero methane emissions to the atmosphere.
(ii) The barrier fluid system is in heavy liquid service or does not have the potential to emit methane.
(iii) Each barrier fluid system is equipped with a sensor that will detect failure of the seal system, the barrier fluid system, or both.
(iv) Each pump is checked according to the requirements in paragraph (b)(1) of this section.
(v) Each sensor meets the requirements in paragraphs (b)(2)(v)(A) through (C) of this section.
(A) Each sensor as described in paragraph (b)(2)(iii) of this section is checked daily or is equipped with an audible alarm.
(B) You determine, based on design considerations and operating experience, a criterion that indicates failure of the seal system, the barrier fluid system, or both.
(C) If the sensor indicates failure of the seal system, the barrier fluid system, or both, based on the criterion established in paragraph (b)(2)(v)(B) of this section, a leak is detected.
(3) Any pump that is designated, as described in § 60.5421c(b)(12), for no detectable emissions, as indicated by an instrument reading of less than 500 ppmv above background, is exempt from the requirements of paragraphs (b), (b)(1), and (b)(2) of this section if the pump:
(i) Has no externally actuated shaft penetrating the pump housing;
(ii) Is demonstrated to be operating with no detectable emissions as indicated by an instrument reading of less than 500 ppmv above background as measured by the methods specified in § 60.5406c; and
(iii) Is tested for compliance with paragraph (b)(3)(ii) of this section initially upon designation, annually, and at other times requested by the Administrator.
(4) If any pump is equipped with a closed vent system capable of capturing and transporting any leakage from the seal or seals to a process, fuel gas system, or a control device that complies with the requirements of paragraph (e) of this section, it is exempt from paragraphs (b) introductory text and (b)(1) through (3) of this section, and the repair requirements of paragraph (i) of this section.
(5) Any pump that is designated, as described in § 60.5421c(b)(13), as an unsafe-to-monitor pump is exempt from the monitoring and inspection requirements of paragraphs (b) introductory text, (b)(1), and (b)(2)(iv) and (v) of this section if the conditions in paragraph (b)(5)(i) and (ii) are met.
(i) You demonstrate that the pump is unsafe-to-monitor because monitoring personnel would be exposed to an immediate danger as a consequence of complying with paragraph (b) of this section; and
(ii) You have a written plan that requires monitoring of the pump as frequently as practicable during safe-to-monitor times, but not more frequently than the periodic monitoring schedule otherwise applicable, and you repair the equipment according to the procedures in paragraph (i) of this section if a leak is detected.
(6) Any pump that is located within the boundary of an unmanned plant site is exempt from the weekly visual inspection requirements in paragraph (b)(1) and (b)(2)(iv) of this section, and the daily requirements of paragraph (b)(2)(v) of this section, provided that each pump is visually inspected as often as practicable and at least monthly.
(c) * * *
(5) Pressure relief devices equipped with a rupture disk are exempt from the requirements of paragraphs (c)(1) and (2) of this section provided you install a new rupture disk upstream of the pressure relief device as soon as practicable, but no later than 5 calendar days after each pressure release, except as provided in paragraph (i)(6) of this section.
* * * * *(f) Valves in gas/vapor and light liquid service. You must monitor each valve in gas/vapor and in light liquid service quarterly to detect leaks by the methods specified in § 60.5406c, except as provided in paragraphs (f)(3) through (5) of this section.
(1) A valve that begins operation in gas/vapor service or in light liquid service after the initial startup date for the process unit must be monitored for the first time within 90 days after the end of its startup period to ensure proper installation, except for a valve that replaces a leaking valve and except as provided in paragraphs (f)(3) through (5) of this section.
(2) An instrument reading of 500 ppmv or greater is a leak. You must repair each leaking valve according to the requirements in paragraph (i) of this section.
(3) Any valve that is designated, as described in § 60.5421c(b)(12), for no detectable emissions, as indicated by an instrument reading of less than 500 ppmv above background, is exempt from the monitoring requirements of paragraph (f) of this section if the valve:
(i) Has no externally actuating mechanism in contact with the process fluid;
(ii) Is operated with emissions less than 500 ppmv above background as determined by the methods specified in § 60.5406c; and
(iii) Is tested for compliance with paragraph (f)(3)(ii) of this section initially upon designation, annually, and at other times requested by the Administrator.
(4) Any valve that is designated, as described in § 60.5421c(b)(13), as an unsafe-to-monitor valve is exempt from the monitoring requirements of paragraph (f) of this section if the requirements in paragraphs (f)(4)(i) and (ii) of this section are met.
(i) You demonstrate that the valve is unsafe-to-monitor because monitoring personnel would be exposed to an immediate danger as a consequence of complying with paragraph (f) of this section; and
(ii) You have a written plan that requires monitoring of the valve as frequently as practicable during safe-to-monitor times, but not more frequently than the periodic monitoring schedule otherwise applicable, and you repair the equipment according to the procedures in paragraph (i) of this section if a leak is detected.
(5) Any valve that is designated, as described in § 60.5421c(b)(14), as a difficult-to-monitor valve is exempt from the monitoring requirements of paragraph (f) of this section if the requirements in paragraph (f)(5)(i) through (iii) of this section are met.
(i) You demonstrate that the valve cannot be monitored without elevating the monitoring personnel more than 2 meters above a support surface.
(ii) The process unit within which the valve is located has less than 3.0 percent of its total number of valves designated as difficult-to-monitor.
(iii) You have a written plan that requires monitoring of the at least once per calendar year.
* * * * *(l) Reporting. You must perform the reporting requirements as specified in § 60.5420c(b)(1) and (10) through (12), as applicable, and § 60.5422c.
(m) Recordkeeping. You must perform the recordkeeping requirements as specified in § 60.5420c(c)(7) and (9) through (12), as applicable, and § 60.5421c.
52. Amend § 60.5402c by revising paragraph (d) introductory text to read as follows:
What are the exceptions to the GHG standards for process unit equipment designated facilities?* * * * *(d) You may use the following provisions instead of § 60.5406c(d):
* * * * *53. Amend § 60.5405c by revising paragraphs (a) introductory text, (a)(2), and (c)(4)(ii) to read as follows:
What test methods and procedures must I use for my centrifugal compressor and reciprocating compressor designated facilities?(a) You must use one of the methods described in paragraphs (a)(1) and (2) of this section to screen for emissions or leaks from the reciprocating compressor rod packing when complying with § 60.5393c(b)(1)(iii), (b)(2)(i), or (c)(2)(iv), and from the compressor dry and wet seal vents when complying with § 60.5392c(a)(2)(i)(A).
* * * * *(2) Method 21. Use Method 21 in appendix A-7 to this part according to § 60.5406c(b)(1) and (2). For the purposes of this section, an instrument reading of 500 ppmv above background or greater is a leak.
* * * * *(c) * * *
(4) * * *
(ii) The flow measurement sensor(s) must be capable of taking a measurement once every second, and the data system must be capable of recording these results for each sensor at all times during operation of the sampler.
* * * * *54. Amend § 60.5406c by revising paragraph (c) introductory text to read as follows:
What test methods and procedures must I use for my process unit equipment designated facilities?* * * * *(c) You shall determine compliance with the no detectable emission standards in § 60.5401c(b) and (f) as specified in paragraphs (c)(1) and (2) of this section.
* * * * *55. Section 60.5410c is revised and republished to read as follows:
How do I demonstrate initial compliance with the standards for each of my designated facilities?(a) Gas well liquids unloading standards for well designated facility. To demonstrate initial compliance with the GHG standards for each gas well liquids unloading operation conducted at your well designated facility as required by § 60.5390c, you must comply with paragraphs (a)(1) through (4) of this section, as applicable.
(1) You must submit the initial annual report for your well designated facility as required in § 60.5420c(b)(1) and (2).
(2) If you comply by using a liquids unloading technology or technique that does not vent to the atmosphere according to § 60.5390c(a)(1), you must maintain the records specified in § 60.5420c(c)(1)(i).
(3) If you comply by using a liquids unloading technology or technique that vents to the atmosphere according to § 60.5390c(a)(2), (b) and (c), you must comply with paragraphs (a)(3)(i) and (ii) of this section.
(i) Employ best management practices to minimize venting of methane emissions as specified in § 60.5390c(c) for each gas well liquids unloading operation.
(ii) Maintain the records specified in § 60.5420c(c)(1)(ii).
(4) If you comply by using § 60.5390c(g), you must comply with paragraphs (b)(4)(i) through (vi) of this section.
(i) Reduce methane emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413c.
(ii) Install a closed vent system that meets the requirements of § 60.5411c(a) and (c) to capture all emissions and route all emissions to a control device that meets the conditions specified in § 60.5412c.
(iii) Conduct an initial performance test as required in § 60.5413c within 180 days after the initial gas well liquids unloading operation or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e), and comply with the continuous compliance requirements of § 60.5415c(e).
(iv) Conduct the initial inspections required in § 60.5416c(a) and (b).
(v) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(vi) Maintain the records specified in § 60.5420c(c)(1)(iii), (c)(7), and (c)(9) through (12), as applicable and submit the reports as required by § 60.5420c(b)(10) through (12), as applicable.
(b) Associated gas well standards for well designated facility. To demonstrate initial compliance with the GHG standards for each associated gas well as required by § 60.5391c, you must comply with paragraphs (b)(1) through (5) of this section.
(1) If you comply with the requirements of § 60.5391c(a), you must maintain the records specified in § 60.5420c(c)(2)(i) and (ii), as applicable, and submit the information required by § 60.5420c(b)(3)(i) through (v) in your initial annual report.
(2) If you comply with § 60.5391c(b) because you have demonstrated that annual methane emissions are 40 tons per year or less, you must document the calculation of annual methane emissions determined in accordance with § 60.5391c(e)(1) and submit them in the initial annual report as required by paragraph (b)(5) of this section, and comply with paragraphs (b)(4) of this section.
(3) If you comply with § 60.5391c(b) because you have demonstrated that it is not feasible to comply with § 60.5391c(a)(1), (2), (3), or (4) due to technical reasons, document the initial demonstration and certification of the technical reason in accordance with § 60.5391c(b)(2), maintain the documentation in accordance with § 60.5391c(b)(2)(iv), and comply with paragraphs (b)(4) of this section. Submit this documentation in the initial annual report as required by paragraph (b)(5) of this section and comply with paragraph (b)(4) of this section.
(4) If you comply with § 60.5391c(b) or (c), you must comply with paragraphs (b)(4)(i) through (vi) of this section.
(i) Reduce methane emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413c.
(ii) Install a closed vent system that meets the requirements of § 60.5411c(a) and (c) to capture the associated gas and route the captured associated gas to a control device that meets the conditions specified in § 60.5412c.
(iii) Conduct an initial performance test as required in § 60.5413c within 180 days after initial startup or by 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e) and you must comply with the continuous compliance requirements of § 60.5415c(e).
(iv) Conduct the initial inspections required in § 60.5416c(a) and (b).
(v) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(vi) Maintain the records specified in § 60.5420c(c)(2)(ii) and (v) and (c)(7) and (9) through (12), as applicable.
(5) You must submit the initial annual report for your associated gas well at a well designated facility as required in § 60.5420c(b)(1), (3), and (10) through (12), as applicable.
(c) Centrifugal compressor designated facility. To demonstrate initial compliance with the GHG standards in § 60.5392c(a)(1) and (2) for your centrifugal compressors (including both wet seal centrifugal compressors and dry seal centrifugal compressors) that require volumetric flow rate measurements, you must comply with paragraphs (c)(1), (6), and (7) of this section. Alternatively, if you comply with the GHG standards for your wet seal and dry seal centrifugal compressor designated facility by reducing methane emissions from each centrifugal compressor wet seal fluid degassing system by 95.0 percent in accordance with § 60.5392c(a)(3) and (4), you must achieve initial compliance by complying with paragraphs (c)(2) through (7) of this section. If you comply with the GHG standards for your wet seal and dry seal centrifugal compressor designated facility by routing emissions from the wet seal fluid degassing system through a closed vent system to a process in accordance with § 60.5392c(a)(5), you must achieve initial compliance by complying with paragraphs (c)(2), (4), (6), and (7) of this section.
(1) You must maintain the volumetric flow rates for your centrifugal compressors as specified in paragraphs (c)(1)(i) through (iii) of this section, as applicable. You must conduct your initial annual volumetric measurement as required by § 60.5392c(a)(1).
(i) For your wet seal centrifugal compressors (including self-contained wet seal centrifugal compressors), you must maintain the volumetric flow rate at or below 3 scfm per seal.
(ii) For your Alaska North Slope centrifugal compressor equipped with sour seal oil separator and capture system, you must maintain the volumetric flow rate at or below 9 scfm per seal.
(iii) For your dry seal compressor, you must maintain the volumetric flow rate at or below 10 scfm per seal.
(2) If you use a control device to reduce emissions to comply with § 60.5392c(a)(4) or route the emissions to a process to comply with § 60.5392c(a)(5), you must equip the wet seal fluid degassing system or dry seal system with a cover that meets the requirements of § 60.5411c(b) and route the captured vapors through a closed vent system that meets the requirements of § 60.5411c(a) and (c) and is routed to a control device or process.
(3) If you use a control device to comply with § 60.5392c(a)(4), you must conduct an initial performance test as required in § 60.5413c within 180 days after initial startup, or by 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e) and you must comply with the continuous compliance requirements of § 60.5415c(e).
(4) If you use a control device to comply with § 60.5392c(a)(4) or comply with § 60.5392c(a)(5) by routing to a process, you must conduct the initial inspections required in § 60.5416c(a) and (b).
(5) If you use a control device to comply with § 60.5392c(a)(4), you must install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(6) You must submit the initial annual report for your centrifugal compressor designated facility as required in § 60.5420c(b)(1) and (4) and (b)(10) through (12), as applicable.
(7) You must maintain the records as specified in § 60.5420c(c)(3) and (c)(7) through (12), as applicable.
(d) Reciprocating compressor designated facility. To demonstrate initial compliance with the GHG standards for each reciprocating compressor designated facility as required by § 60.5393c, you must comply with paragraphs (d)(1) through (7) of this section.
(1) If you comply with § 60.5393c(a) by maintaining volumetric flow rate at or below 2 scfm per cylinder (or a combined cylinder emission flow rate greater than the number of compression cylinders multiplied by 2 scfm) as required by § 60.5393c(a), you must maintain volumetric flow rate at or below 2 scfm and you must conduct your initial annual volumetric flow rate measurement as required by § 60.5393c(a)(1).
(2) If you comply with § 60.5393c by collecting the methane emissions from your reciprocating compressor rod packing using a rod packing emissions collection system to a process as required by § 60.5393c(d)(1), you must equip the reciprocating compressor with a cover that meets the requirements of § 60.5411c(b), route emissions to a process through a closed vent system that meets the requirements of § 60.5411c(a) and (c), and you must conduct the initial inspections required in § 60.5416c(a) and (b).
(3) If you comply with § 60.5393c(d) by collecting emissions from your rod packing emissions collection system by using a control device to reduce methane emissions by 95.0 percent as required by § 60.5393c(d)(2), you must equip the reciprocating compressor with a cover that meets the requirements of § 60.5411c(b), route emissions to a control device that meets the conditions specified in § 60.5412c through a closed vent system that meets the requirements of § 60.5411c(a) and (c), and you must conduct the initial inspections required in § 60.5416c(a) and (b).
(4) If you comply with § 60.5393c(d)(2), you must conduct an initial performance test as required in § 60.5413c within 180 days after initial startup, or by 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e) and you must comply with the continuous compliance requirements of § 60.5415c(e).
(5) If you comply with § 60.5393c(d)(2), you must install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(6) You must submit the initial annual report for your reciprocating compressor as required in § 60.5420c(b)(1), (5), and (10) through (12), as applicable.
(7) You must maintain the records as specified in § 60.5420c(c)(4) and (7) through (12), as applicable.
(e) Process controller designated facility. To demonstrate initial compliance with GHG emission standards for your process controller designated facility, you must comply with paragraphs (e)(1) through (5) of this section, as applicable. If you change compliance methods, you must also perform the applicable compliance demonstrations of paragraphs (e)(1) through (3) of this section again for the new compliance method, note the change in compliance method in the annual report required by § 60.5420c(b)(6)(iv), and maintain the records required by paragraph (e)(1)(i) or (ii) of this section, as applicable, for the new compliance method.
(1) For process controller designated facilities complying with the requirements of § 60.5394c(a), you must demonstrate that your process controller designated facility does not emit any methane to the atmosphere by meeting the requirements of paragraphs (e)(1)(i) and (ii) of this section.
(i) If you comply by routing the emissions to a process, you must meet the requirements for closed vent systems specified in paragraph (e)(3) of this section.
(ii) If you comply by using a self-contained natural gas-driven process controller, you must conduct an initial no identifiable emissions inspection required by § 60.5416c(b).
(2) For each process controller designated facility located at a site in Alaska that does not have access to electrical power, you must demonstrate initial compliance with § 60.5394c(b)(1) and (2) or with § 60.5394c(b)(3), as an alternative to complying with paragraph § 60.5394c(a) by meeting the requirements specified in (e)(2)(i) through (v) of this section for each process controller, as applicable.
(i) For each process controller in the process controller designated facility operating with a bleed rate of less than or equal to 6 scfh, you must maintain records in accordance with § 60.5420c(c)(5)(iii)(A) that demonstrate the process controller is designed and operated to achieve a bleed rate less than or equal to 6 scfh.
(ii) For each process controller in the process controller designated facility operating with a bleed rate greater than 6 scfh, you must maintain records that demonstrate that a controller with a higher bleed rate than 6 scfh is required based on a specific functional need for that controller as specified in § 60.5420c(c)(5)(iii)(B).
(iii) For each intermittent vent process controller in the process controller designated facility you must demonstrate that each intermittent vent controller does not emit to the atmosphere during idle periods by conducting initial monitoring in accordance with § 60.5394c(b)(2)(ii).
(iv) For each process controller designated facility that complies by reducing methane emissions from all controllers in the process controller designated facility by 95.0 percent in accordance with § 60.5394c(b)(3), you must comply with paragraphs (e)(2)(iv)(A) through (D) of this section.
(A) Reduce methane emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413c.
(B) Route all process controller designated facility emissions to a control device that meets the conditions specified in § 60.5412c through a closed vent system that meets the requirements specified in paragraph (e)(3) of this section.
(C) Conduct an initial performance test as required in § 60.5413c within 180 days after initial startup, or by 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e) and you must comply with the continuous compliance requirements of § 60.5415c(e).
(D) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(3) For each closed vent system used to comply with § 60.5394c, you must meet the requirements specified in paragraphs (e)(3)(i) and (ii) of this section.
(i) Install a closed vent system that meets the requirements of § 60.5411c(a) and (c).
(ii) Conduct the initial inspections of the closed vent system and bypasses, if applicable, as required in § 60.5416c(a) and (b).
(4) You must submit the initial annual report for your process controller designated facility as required in § 60.5420c(b)(1) and (6).
(5) You must maintain the records as specified in § 60.5420c(c)(5).
(f) Pump designated facility. To demonstrate initial compliance with the GHG standards for your pump designated facility as required by § 60.5395c, you must comply with paragraphs (f)(1) through (4) of this section, as applicable. If you change compliance methods, you must also perform the applicable compliance demonstrations of paragraphs (f)(1) and (2) of this section again for the new compliance method, note the change in compliance method in the annual report required by § 60.5420c(b)(9)(v), and maintain the records required by paragraph (f)(4) of this section for the new compliance method.
(1) For pump designated facilities complying with the requirements of § 60.5395c(a) or (b)(2) by routing emissions to a process, you must meet the requirements specified in paragraphs (f)(1)(ii) and (iv) of this section. For pump designated facilities complying with the requirements of § 60.5395c(b)(3), you must meet the requirements specified in paragraphs (f)(1)(i) through (v) of this section.
(i) Reduce methane emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413c.
(ii) Install a closed vent system that meets the requirements of § 60.5411c(a) and (c) to capture all emissions from all pumps in the pump designated facility and route all emissions to a process or control device that meets the conditions specified in § 60.5412c.
(iii) Conduct an initial performance test as required in § 60.5413c within 180 days after initial startup, or by 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e), and you must comply with the continuous compliance requirements of § 60.5415c(e).
(iv) Conduct the initial inspections of the closed vent system and bypasses, if applicable, as required in § 60.5416c(a) and (b).
(v) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(2) Submit the certifications specified in paragraphs (f)(2)(i) through (iii) of this section, as applicable.
(i) The certification required by § 60.5395c(b)(3) that there is no vapor recovery unit on site and that there is a control device on site, but it does not achieve a 95.0 percent emissions reduction.
(ii) The certification required by § 60.5395c(b)(4) that there is no control device or process available on site.
(iii) The certification required by § 60.5395c(b)(7)(i) that it is technically infeasible to capture and route the pump designated facility emissions to a process or an existing control device.
(3) You must submit the initial annual report for your pump designated facility as specified in § 60.5420c(b)(1) and (9) through (12), as applicable.
(4) You must maintain the records for your pump designated facility as specified in § 60.5420c(c)(7) and (9) through (12), as applicable, and (c)(14).
(g) Process unit equipment designated facility. To achieve initial compliance with the GHG standards for process unit equipment designated facilities as required by § 60.5400c, you must comply with paragraphs (g)(1) through (4) and (11) through (15) of this section, unless you meet and comply with the exception in § 60.5402c(b), (e), or (f) or meet the exemption in § 60.5402c(c). If you comply with the GHG standards for process unit equipment designated facilities using the alternative standards in § 60.5401c, you must comply with paragraphs (g)(5) through (15) of this section, unless you meet and comply with the exemption in § 60.5402c(b) or (c) or the exception in § 60.5402c(e) or (f).
(1) You must conduct monitoring for each pump in light liquid service, pressure relief device in gas/vapor service, valve in gas/vapor or light liquid service and connector in gas/vapor or light liquid service as required by § 60.5400c(b).
(2) You must conduct monitoring as required by § 60.5400c(c) for each pump in light liquid service.
(3) You must conduct monitoring as required by § 60.5400c(d) for each pressure relief device in gas/vapor service.
(4) You must comply with the equipment requirements for each open-ended valve or line as required by § 60.5400c(e).
(5) You must conduct monitoring for each pump in light liquid service as required by § 60.5401c(b).
(6) You must conduct monitoring for each pressure relief device in gas/vapor service as required by § 60.5401c(c).
(7) You must comply with the equipment requirements for each open-ended valve or line as required by § 60.5401c(d).
(8) You must conduct monitoring for each valve in gas/vapor or light liquid service as required by § 60.5401c(f).
(9) You must conduct monitoring for each pump, valve, and connector in heavy liquid service and each pressure relief device in light liquid or heavy liquid service as required by § 60.5401c(g).
(10) You must conduct monitoring for each connector in gas/vapor or light liquid service as required by § 60.5401c(h).
(11) For each pump equipped with a dual mechanical seal system that degasses the barrier fluid reservoir to a process or a control device, each pump which captures and transports leakage from the seal or seals to a process or a control device, or each pressure relief device which captures and transports leakage through the pressure relief device to a process or a control device, you must meet the requirements of paragraph (g)(11)(i) through (vi) of this section.
(i) Reduce methane emissions by 95.0 percent or greater and as demonstrated by the requirements of § 60.5413c or route to a process.
(ii) Install a closed vent system that meets the requirements of § 60.5411c(a) and (c) to capture all emissions from each pump equipped with a dual mechanical seal system that degasses the barrier fluid reservoir, each pump which captures and transports leakage from the seal or seals, or each pressure relief device which captures and transports leakage through the pressure relief device and route all emissions to a process or to a control device that meets the conditions specified in § 60.5412c.
(iii) If routing to a control device, conduct an initial performance test as required in § 60.5413c within 180 days after initial startup, or by 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e), and you must comply with the continuous compliance requirements of § 60.5415c(e).
(iv) Conduct the initial inspections of the closed vent system and bypasses, if applicable, as required in § 60.5416c(a) and (b).
(v) Install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(vi) Maintain the records as required by § 60.5420c(c)(7) and (c)(9) through (12), as applicable and submit the reports as required by § 60.5420c(b)(10) through (12), as applicable.
(12) You must tag and repair each identified leak as required in § 60.5400c(h) or § 60.5401c(i), as applicable.
(13) You must submit the notice required by § 60.5420c(a)(2).
(14) You must submit the initial semiannual report and subsequent semiannual report as required by § 60.5422c.
(15) You must maintain the records specified by § 60.5421c.
(h) Storage vessel designated facility. To achieve initial compliance with the GHG standards for each storage vessel designated facility as required by § 60.5396c, you must comply with paragraphs (h)(1) through (9) of this section. To achieve initial compliance with the GHG standards for each storage vessel designated facility that complies by using a floating roof in accordance with § 60.5396c(b)(2), you must comply with paragraph (h)(1) and (10) of this section.
(1) You must determine the potential for methane emissions as specified in § 60.5386c(e)(2).
(2) You must reduce methane emissions by 95.0 percent or greater according to § 60.5396c(a) and as demonstrated by the requirements of § 60.5413c or route to a process.
(3) If you use a control device to reduce emissions, you must equip each storage vessel in the storage vessel designated facility with a cover that meets the requirements of § 60.5411c(b), install a closed vent system that meets the requirements of § 60.5411c(a) and (c) to capture all emissions from the storage vessel designated facility, and route all emissions to a control device that meets the conditions specified in § 60.5412c. If you route emissions to a process, you must equip each storage vessel in the storage vessel affected facility with a cover that meets the requirements of § 60.5411c(b), install a closed vent system that meets the requirements of § 60.5411c(a) and (c) to capture all emissions from the storage vessel affected facility, and route all emissions to a process.
(4) If you use a control device to reduce emissions, you must conduct an initial performance test as required in § 60.5413c within 180 days after initial startup, or within 180 days 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), whichever date is later, or install a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e), and you must comply with the continuous compliance requirements of § 60.5415c(e).
(5) You must conduct the initial inspections of the closed vent system and bypasses, if applicable, as required in § 60.5416c(a) and (b).
(6) You must install and operate the continuous parameter monitoring systems in accordance with § 60.5417c(a) through (i), as applicable.
(7) You must maintain the records as required by § 60.5420c(c)(7) through (12), as applicable and submit the reports as required by § 60.5420c(b)(10) through (12), as applicable.
(8) You must submit the initial annual report for your storage vessel designated facility required by § 60.5420c(b)(1) and (7).
(9) You must maintain the records required for your storage vessel designated facility, as specified in § 60.5420c(c)(6) for each storage vessel designated facility.
(10) For each storage vessel designated facility that complies by using a floating roof, you must meet the requirements of § 60.112b(a)(1) or (2) and the relevant monitoring, inspection, recordkeeping, and reporting requirements in subpart Kb of this part. You must submit a statement that you are complying with § 60.112b(d)(a)(1) or (2) in accordance with § 60.5396c(b)(2) with the initial annual report specified in § 60.5420c(b)(1) and (7).
(i) Fugitive emission components designated facility. To achieve initial compliance with the GHG standards for fugitive emissions components designated facilities as required by § 60.5397c, you must comply with paragraphs (i)(1) through (5) of this section.
(1) You must develop a fugitive emissions monitoring plan as required in § 60.5397c(b), (c), and (d).
(2) You must conduct an initial monitoring survey as required in § 60.5397c(e) and (f).
(3) You must repair each identified source of fugitive emissions for each designated facility as required in § 60.5397c(h).
(4) You must submit the initial annual report for each fugitive emissions components designated facility as required in § 60.5420c(b)(1) and (8).
(5) You must maintain the records specified in § 60.5420c(c)(13).
56. Amend § 60.5411c by revising paragraph (b)(4) to read as follows:
What additional requirements must I meet to determine initial compliance for my covers and closed vent systems?* * * * *(b) * * *
(4) You must design and operate the cover with no identifiable emissions as demonstrated by § 60.5416c(a) and (b), except when operated as provided in paragraphs (b)(2)(i) through (iv) of this section.
* * * * *57. Amend § 60.5412c by revising paragraphs (a) introductory text, (a)(3)(iii) and (iv), and (c)(1)(i) to read as follows:
What additional requirements must I meet for determining initial compliance of my control devices?* * * * *(a) Each control device used to meet the emissions reduction standard in § 60.5390c(g) for your well designated facility gas well that unloads liquids; § 60.5391c(b) or (c) for your well designated facility with associated gas; § 60.5392c(a)(4) for your centrifugal compressor designated facility; § 60.5393c(d)(2) for your reciprocating compressor designated facility; § 60.5396c(a)(2) for your storage vessel designated facility; § 60.5394c(b)(3) for your process controller designated facility in Alaska; § 60.5395c(b)(3) for your pumps designated facility; or either § 60.5400c(f) or § 60.5401c(e) for your process equipment designated facility must be installed according to paragraphs (a)(1) through (3) of this section. As an alternative to paragraphs (a)(1) through (3) of this section, you may install a control device model tested under § 60.5413c(d), which meets the criteria in § 60.5413c(d)(11) and which meets the initial and continuous compliance requirements in § 60.5413c(e).
* * * * *(3) * * *
(iii) For steam-assisted and air-assisted flares, you must maintain the NHVcz at or above 270 Btu/scf.
(iv) For flares with perimeter assist air, you must maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the flare is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are not required to comply with the NHVdil limit.
* * * * *(c) * * *
(1) * * *
(i) Following the initial startup of the control device, you must replace all carbon in the carbon adsorption system with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established according to § 60.5413c(c)(2) or (3). You must maintain records identifying the schedule for replacement and records of each carbon replacement as required in § 60.5420c(c)(10).
* * * * *58. Amend § 60.5413c by revising the introductory text to read as follows:
What are the performance testing procedures for control devices?This section applies to the performance testing of control devices used to demonstrate compliance with the emissions standards for your well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment designated facilities. You must demonstrate that a control device achieves the performance requirements of § 60.5412c(a)(1) or (2) using the performance test methods and procedures specified in this section. For condensers and carbon adsorbers, you may use a design analysis as specified in paragraph (c) of this section in lieu of complying with paragraph (b) of this section. In addition, this section contains the requirements for enclosed combustion device performance tests conducted by the manufacturer applicable to well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment designated facilities.
* * * * *59. Section 60.5415c is revised and republished to read as follows:
How do I demonstrate continuous compliance with the standards for each of my designated facilities?(a) Gas well liquids unloading standards for well designated facility. For each well liquids unloading operation at your well designated facility, you must demonstrate continuous compliance with the requirements of § 60.5390c by submitting the annual report information specified in § 60.5420c(b)(1) and (2) and maintaining the records for each well liquids unloading event that vents to the atmosphere as specified in § 60.5420c(c)(1). For each gas well liquids unloading well designated facility that complies with the requirements of § 60.5390c(g), you must route emissions to a control device through a closed vent system and continuously comply with the closed vent requirements of § 60.5416c. You also must comply with the requirements specified in paragraph (e) of this section and maintain the reports in § 60.5420c(b)(10)(i) through (iv) and maintain the records in § 60.5420c(c)(7), (9), and (11).
(b) Associated gas well standards for well designated facility. For each associated gas well at your well designated facility, you must demonstrate continuous compliance with the requirements of § 60.5391c by submitting the reports required by § 60.5420c(b)(1) and (3) and maintaining the records specified in § 60.5420c(c)(2). For each associated gas well at your well designated facility that complies with the requirements of § 60.5391c(b) or (c), you must route emissions to a control device through a closed vent system and continuously comply with the closed vent requirements of § 60.5416c. You must also comply with the requirements specified in paragraph (e) of this section and maintain the records in paragraphs (c)(7), (9) and (11) of this section.
(c) Centrifugal compressor designated facility. For each centrifugal compressor designated facility complying with the volumetric flow rate measurements requirements in § 60.5392c(a)(1) and (2), you must demonstrate continuous compliance according to paragraph (c)(1) and paragraphs (c)(3) and (4) of this section. Alternatively, for each centrifugal compressor designated facility complying with § 60.5392c(a)(3) and either (a)(4) or (5) by routing emissions to a control device or to a process, you must demonstrate continuous compliance according to paragraphs (c)(2) through (4) of this section.
(1) You must maintain volumetric flow rate at or below the volumetric flow rates specified in paragraphs (c)(1)(i) through (iii) of this section for your centrifugal compressor, as applicable, and you must conduct the required volumetric flow rate measurement of your dry or wet seal in accordance with § 60.5392c(a)(1) and (2) on or before 8,760 hours of operation after your last volumetric flow rate measurement which demonstrates compliance with the applicable volumetric flow rate.
(i) For your wet seal centrifugal compressors (including self-contained wet seal centrifugal compressors), you must maintain the volumetric flow rate at or below 3 scfm per seal (or in the case of manifolded groups of seals, 3 scfm multiplied by the number of seals).
(ii) For your Alaska North Slope centrifugal compressor equipped with sour seal oil separator and capture system, you must maintain the volumetric flow rate at or below 9 scfm per seal (or in the case of manifolded groups of wet seals, 9 scfm multiplied by the number of seals).
(iii) For your dry seal compressor, you must maintain the volumetric flow rate at or below 10 scfm per seal (or in the case of manifolded groups of wet seals, 10 scfm multiplied by the number of seals).
(2) For each wet seal and dry seal centrifugal compressor designated facility complying by routing emissions to a control device or to a process, you must operate the wet seal emissions collection system and dry seal system to route emissions to a control device or a process through a closed vent system and continuously comply with the closed vent requirements of § 60.5416c. If you comply with § 60.5392c(a)(4) by using a control device, you also must comply with the requirements in paragraph (e) of this section.
(3) You must submit the annual reports as required in § 60.5420c(b)(1), (4) and (10)(i) through (iv), as applicable.
(4) You must maintain records as required in § 60.5420c(c)(3), (7) through (9) and (11), as applicable.
(d) Pump designated facility. To demonstrate continuous compliance with the GHG standards for your pump designated facility as required by § 60.5395c, you must comply with paragraphs (d)(1) through (3) of this section.
(1) For pump designated facilities complying with the requirements of § 60.5395c(a) by routing emissions to a process and for pump designated facilities complying with the requirements of § 60.5395c(b)(2) or (3), you must continuously comply with the closed vent system requirements of § 60.5416c. If you comply with § 60.5395c(b)(3), you also must comply with the requirements in paragraph (e) of this section.
(2) You must submit the annual reports for your pump designated facility as required in § 60.5420c(b)(1) and (9) and (b)(10)(i) through (iv), as applicable.
(3) You must maintain the records for your pump designated facility as specified in § 60.5420c(c)(7), (9), (11), and (14), as applicable.
(e) Additional continuous compliance requirements for well, centrifugal compressor, reciprocating compressor, process controllers in Alaska, storage vessel, process unit equipment, or pump designated facilities. For each associated gas well at your well designated facility, each gas well liquids unloading operation at your well designated facility, each centrifugal compressor designated facility, each reciprocating compressor designated facility, each process controller designated facility in Alaska, each storage vessel designated facility, each process unit equipment designated facility, and each pump designated facility referenced to this paragraph from paragraph (a), (b), (c)(2), (d)(1), (f)(2), (g)(2), (h)(5)(ii)(B), or (i)(12) of this section, you must also install monitoring systems as specified in § 60.5417c, demonstrate continuous compliance according to paragraph (e)(1) of this section, maintain the records in paragraph (e)(2) of this section, and comply with the reporting requirements specified in paragraph (e)(3) of this section.
(1) You must demonstrate continuous compliance with the control device performance requirements of § 60.5412c(a) using the procedures specified in paragraphs (e)(1)(i) through (viii) of this section and conducting the monitoring as required by § 60.5417c. If you use a condenser as the control device to achieve the requirements specified in § 60.5412c(a)(2), you may demonstrate compliance according to paragraph (e)(1)(ix) of this section. You may switch between compliance with paragraphs (e)(1)(i) through (viii) of this section and compliance with paragraph (e)(1)(ix) of this section only after at least 1 year of operation in compliance with the selected approach. You must provide notification of such a change in the compliance method in the next annual report, following the change. If you use an enclosed combustion device or a flare as the control device, you must also conduct the monitoring required in paragraph (e)(1)(x) of this section. If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d), you must use the procedures in paragraph (e)(1)(xi) of this section in lieu of the procedures in paragraphs (e)(1)(i) through (viii) of this section, but you must still conduct the monitoring required in paragraph (e)(1)(x) of this section.
(i) You must operate below (or above) the site-specific maximum (or minimum) parameter value established according to the requirements of § 60.5417c(f)(1). For flares, you must operate above the limits specified in paragraphs (e)(1)(vii)(B) of this section.
(ii) You must calculate the average of the applicable monitored parameter in accordance with § 60.5417c(e).
(iii) Compliance with the operating parameter limit is achieved when the average of the monitoring parameter value calculated under paragraph (e)(1)(ii) of this section is either equal to or greater than the minimum parameter value or equal to or less than the maximum parameter value established under paragraph (e)(1)(i) of this section. When performance testing of a combustion control device is conducted by the device manufacturer as specified in § 60.5413c(d), compliance with the operating parameter limit is achieved when the criteria in § 60.5413c(e) are met.
(iv) You must operate the continuous monitoring system required in § 60.5417c(a) at all times the affected source is operating, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments). A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. You are required to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
(v) You may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report emissions or operating levels. You must use all the data collected during all other required data collection periods to assess the operation of the control device and associated control system.
(vi) Failure to collect required data is a deviation of the monitoring requirements.
(vii) If you use an enclosed combustion device to meet the requirements of § 60.5412c(a)(1) and you demonstrate compliance using the test procedures specified in § 60.5413c(b), or you use a flare designed and operated in accordance with § 60.5412c(a)(3), you must comply with the applicable requirements in paragraphs (e)(1)(vii)(A) through (E) of this section.
(A) For each enclosed combustion device which is not a catalytic vapor incinerator and for each flare, you must comply with the requirements in paragraphs (e)(1)(vii)(A)( 1) through ( 4) of this section.
( 1) A pilot or combustion flame must be present at all times of operation. An alert must be sent to the nearest control room whenever the pilot or combustion flame is unlit.
( 2) Devices must be operated with no visible emissions, except for periods not to exceed a total of 1 minute during any 15-minute period. A visible emissions test conducted according to section 11 of Method 22 of appendix A-7 to this part, must be performed at least once every calendar month, separated by at least 15 days between each test. The observation period shall be 15 minutes or once the amount of time visible emissions is present has exceeded 1 minute, whichever time period is less. Alternatively, you may conduct visible emissions monitoring according to § 60.5417c(h).
( 3) Devices failing the visible emissions test must follow manufacturer's repair instructions, if available, or best combustion engineering practice as outlined in the unit inspection and maintenance plan, to return the unit to compliant operation. All repairs and maintenance activities for each unit must be recorded in a maintenance and repair log and must be available for inspection.
( 4) Following return to operation from maintenance or repair activity, each device must pass a Method 22 of appendix A-7 to this part visual observation as described in paragraph (e)(1)(vii)(D) of this section or be monitored according to § 60.5417c(h).
(B) For flares, you must comply with the requirements in paragraphs (e)(1)(vii)(B)( 1) through ( 6) of this section.
( 1) For unassisted flares, maintain the NHV of the gas sent to the flare at or above 200 Btu/scf.
( 2) If you use a pressure assisted flare, maintain the NHV of gas sent to the flare at or above 800 Btu/scf.
( 3 ) For steam-assisted and air-assisted flares, maintain the NHVcz at or above 270 Btu/scf.
( 4 ) For flares with perimeter assist air, maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the flare is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are not required to comply with the NHVdil limit.
( 5) Unless you use a pressure-assisted flare, maintain the flare tip velocity below the applicable limits in § 60.18(b).
( 6) Maintain the total gas flow to the flare above the minimum inlet gas flow rate. The minimum inlet gas flow rate is established based on manufacturer recommendations.
(C) For enclosed combustion devices for which, during the performance test conducted under § 60.5413c(b), the combustion zone temperature is not an indicator of destruction efficiency, you must comply with the requirements in paragraphs (e)(1)(vii)(C)( 1) through ( 5) of this section, as applicable.
( 1) Maintain the total gas flow to the enclosed combustion device at or above the minimum inlet gas flow rate and at or below the maximum inlet flow rate for the enclosed combustion device established in accordance with § 60.5417c(f).
( 2) For unassisted enclosed combustion devices, maintain the NHV of the gas sent to the enclosed combustion device at or above 200 Btu/scf.
( 3) For enclosed combustion devices that use pressure-assisted burner tips to promote mixing at the burner tip, maintain the NHV of the gas sent to the enclosed combustion device at or above 800 Btu/scf.
( 4 ) For steam-assisted and air-assisted enclosed combustion devices, maintain the NHVcz at or above 270 Btu/scf.
( 5 ) For enclosed combustion devices with perimeter assist air, maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the enclosed combustion device is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are not required to comply with the NHVdil limit.
(D) For enclosed combustion devices for which, during the performance test conducted under § 60.5413c(b), the combustion zone temperature is demonstrated to be an indicator of destruction efficiency, you must comply with the requirements in paragraphs (e)(1)(vii)(D)( 1) and ( 2) of this section.
( 1) Maintain the temperature at or above the minimum temperature established during the most recent performance test. The minimum temperature limit established during the most recent performance test is the average temperature recorded during each test run, averaged across the 3 test runs (average of the test run averages).
( 2) Maintain the total gas flow to the enclosed combustion device at or above the minimum inlet gas flow rate and at or below the maximum inlet flow rate for the enclosed combustion device established in accordance with § 60.5417c(f).
(E) For catalytic vapor incinerators you must operate the catalytic vapor incinerator at or above the minimum temperature of the catalyst bed inlet and at or above the minimum temperature differential between the catalyst bed inlet and the catalyst bed outlet established in accordance with § 60.5417c(f).
(viii) If you use a carbon adsorption system as the control device to meet the requirements of § 60.5412c(a)(2), you must demonstrate compliance by the procedures in paragraphs (e)(1)(viii)(A) and (B) of this section, as applicable.
(A) If you use a regenerative-type carbon adsorption system, you must comply with paragraphs (e)(1)(viii)(A)( 1) through ( 4) of this section.
( 1) You must maintain the average regenerative mass flow or volumetric flow to the carbon adsorber during each bed regeneration cycle above the limit established in in accordance with § 60.5413c(c)(2).
( 2) You must maintain the average carbon bed temperature above the temperature limit established in accordance with § 60.5413c(c)(2) during the carbon bed steaming cycle and below the carbon bed temperature established in in accordance with § 60.5413c(c)(2) after the regeneration cycle.
( 3) You must check the mechanical connections for leakage at least every month, and you must perform a visual inspection at least every 3 months of all components of the continuous parameter monitoring system for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if your continuous parameter monitoring system is not equipped with a redundant flow sensor.
( 4) You must replace all carbon in the carbon adsorption system with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established according to § 60.5413c(c)(2).
(B) If you use a nonregenerative-type carbon adsorption system, you must replace all carbon in the control device with fresh carbon on a regular, predetermined time interval that is no longer than the carbon service life established according to § 60.5413c(c)(3).
(ix) If you use a condenser as the control device to achieve the percent reduction performance requirements specified in § 60.5412c(a)(2), you must demonstrate compliance using the procedures in paragraphs (e)(1)(ix)(A) through (E) of this section.
(A) You must establish a site-specific condenser performance curve according to § 60.5417c(f)(2).
(B) You must calculate the daily average condenser outlet temperature in accordance with § 60.5417c(e).
(C) You must determine the condenser efficiency for the current operating day using the daily average condenser outlet temperature calculated under paragraph (e)(1)(ix)(B) of this section and the condenser performance curve established under paragraph (e)(1)(ix)(A) of this section.
(D) Except as provided in paragraphs (e)(1)(ix)(D)( 1) and ( 2) of this section, at the end of each operating day, you must calculate the 365-day rolling average TOC emission reduction, as appropriate, from the condenser efficiencies as determined in paragraph (e)(1)(ix)(C) of this section.
( 1) After the compliance dates specified in § 60.5387c, if you have less than 120 days of data for determining average TOC emission reduction, you must calculate the average TOC emission reduction for the first 120 days of operation after the compliance date. You have demonstrated compliance with the overall 95.0 percent reduction requirement if the 120-day average TOC emission reduction is equal to or greater than 95.0 percent.
( 2) After 120 days and no more than 364 days of operation after the compliance date specified in § 60.5387c, you must calculate the average TOC emission reduction as the TOC emission reduction averaged over the number of days between the current day and the applicable compliance date. You have demonstrated compliance with the overall 95.0 percent reduction requirement if the average TOC emission reduction is equal to or greater than 95.0 percent.
(E) If you have data for 365 days or more of operation, you have demonstrated compliance with the TOC emission reduction if the rolling 365-day average TOC emission reduction calculated in paragraph (e)(1)(ix)(D) of this section is equal to or greater than 95.0 percent.
(x) During each inspection conducted using an OGI camera under § 60.5397c and during each periodic screening event or each inspection conducted using an OGI camera under § 60.5398c, you must observe each enclosed combustion device and flare to determine if it is operating properly. You must determine whether there is a flame present and whether any uncontrolled emissions from the control device are visible with the OGI camera or the technique used to conduct the periodic screening event. During each inspection conducted under § 60.5397c using AVO, you must observe each enclosed combustion device and flare to determine if it is operating properly. Visually confirm that the pilot or combustion flame is lit and that the pilot or combustion flame is operating properly.
(xi) If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d), you must comply with paragraphs (e)(1)(xi)(A) through (E) of this section.
(A) You must maintain the combustion efficiency at or above 95.0 percent. Alternatively, if the alternative test method does not directly monitor combustion efficiency, you must comply with the applicable requirements in paragraphs (e)(1)(xi)(A)( 1) and ( 2) of this section.
( 1 ) Maintain the NHVcz at or above 270 Btu/scf.
( 2 ) For flares or enclosed combustion devices with perimeter assist air, maintain the NHVdil at or above 22 Btu/sqft. If the only assist air provided to the flare or enclosed combustion device is perimeter assist air intentionally entrained in lower and/or upper steam at the flare tip and the effective diameter is 9 inches or greater, you are only required to comply with the NHVcz limit specified in paragraph (e)(1)(xi)(A)( 1) of this section.
(B) You must calculate the value of the applicable monitored metric(s) in accordance with the approved alternative test method. Compliance with the limit is achieved when the calculated values are within the range specified in paragraph (e)(1)(xi)(A) of this section.
(C) You must conduct monitoring using the alternative test method at all times the affected source is operating, except for periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities (including, as applicable, system accuracy audits and required zero and span adjustments). A monitoring system malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring system to provide valid data. Monitoring system failures that are caused in part by poor maintenance or careless operation are not malfunctions. You are required to complete monitoring system repairs in response to monitoring system malfunctions and to return the monitoring system to operation as expeditiously as practicable.
(D) You may not use data recorded during monitoring system malfunctions, repairs associated with monitoring system malfunctions, or required monitoring system quality assurance or control activities in calculations used to report values to demonstrate compliance with the limits specified in paragraph (e)(1)(xi)(A) of this section. You must use all the data collected during all other required data collection periods to assess the operation of the control device and associated control system.
(E) Failure to collect required data is a deviation of the monitoring requirements.
(2) You must maintain the records as specified in § 60.5420c(c)(10) and (12).
(3) You must comply with the reporting requirements in § 60.5420c(b)(10) through (12).
(f) Reciprocating compressor designated facility. For each reciprocating compressor designated facility complying with § 60.5393c(a) through (c), you must demonstrate continuous compliance according to paragraphs (f)(1), (3), (5), and (6) of this section. For each reciprocating compressor designated facility complying with § 60.5393c(d)(1) or (2), you must demonstrate continuous compliance according to paragraphs (f)(2), (5), and (6) of this section. For each reciprocating compressor affected facility complying with § 60.5393c(d)(3), you must demonstrate continuous compliance according to paragraphs (f)(3) through (6) of this section.
(1) You must maintain the volumetric flow rate at or below 2 scfm per cylinder (or at or below the combined volumetric flow rate determined by multiplying the number of cylinders by 2 scfm), and you must conduct the required volumetric flow rate measurement of your reciprocating compressor rod packing vents in accordance with § 60.5393c(b) or (c) on or before 8,760 hours of operation after your last volumetric flow rate measurement which demonstrated compliance with the applicable volumetric flow rate.
(2) You must operate the rod packing emissions collection system to route emissions to a control device or to a process through a closed vent system and continuously comply with the cover and closed vent requirements of § 60.5416c. If you comply with § 60.5393c(d) by using a control device, you also must comply with the requirements in paragraph (e) of this section.
(3) You must continuously monitor the number of hours of operation for each reciprocating compressor affected facility since initial startup, since 60 days after the state plan submittal deadline (as specified in § 60.5362c(c)), since the previous flow rate measurement, or since the date of the most recent reciprocating compressor rod packing replacement, whichever date is latest.
(4) You must replace the reciprocating compressor rod packing on or before the total number of hours of operation reaches 8,760 hours.
(5) You must submit the annual reports as required in § 60.5420c(b)(1), (5), and (b)(10)(i) through (iv), as applicable.
(6) You must maintain records as required in § 60.5420c(c)(4), (7) through (9), and (11), as applicable.
(g) Process controller designated facility. To demonstrate continuous compliance with GHG emission standards for your process controller designated facility as required by § 60.5394c, you must comply with the paragraphs (g)(1) through (4) of this section.
(1) You must demonstrate that your process controller designated facility does not emit any methane to the atmosphere by meeting the requirements of paragraphs (g)(1)(i) or (ii) of this section.
(i) If you comply by routing the emissions to a process, you must comply with the closed vent system inspection and monitoring requirements of § 60.5416c.
(ii) If you comply by using a self-contained natural gas-driven process controller, you must conduct the no identifiable emissions inspections required by § 60.5416c(b).
(2) For each process controller designated facility located at a site in Alaska that does not have access to electrical power, and that complies by reducing methane emissions from all controllers in the process controller designated facility by 95.0 percent in accordance with § 60.5494c(b)(3), you must comply with comply with the closed vent requirements of § 60.5416c and the requirements in paragraph (e) of this section for the control device.
(3) You must submit the annual report for your process controller as required in § 60.5420c(b)(1), (6), and (10) through (12), as applicable.
(4) You must maintain the records as specified in § 60.5420c(c)(5), (7), (9), and (11) for each process controller designated facility, as applicable.
(h) Storage vessel designated facility. For each storage vessel designated facility, you must demonstrate continuous compliance with the requirements of § 60.5396c according to paragraphs (h)(1) through (10) of this section, as applicable.
(1) For each storage vessel designated facility complying with the requirements of § 60.5396c(a)(2), you must demonstrate continuous compliance according to paragraphs (h)(5) and (h)(9) and (10) of this section.
(2) For each storage vessel designated facility complying with the requirements of § 60.5396c(a)(3), you must demonstrate continuous compliance according to paragraphs (h)(2)(i), (ii), or (iii) of this section, as applicable, and (h)(9) and (10) of this section.
(i) You must maintain the uncontrolled actual methane emissions from the storage vessel designated facility at less than 14 tpy.
(ii) You must comply with paragraph (h)(5) of this section as soon as liquids from the well are routed to the storage vessel designated facility following fracturing or refracturing according to the requirements of § 60.5396c(a)(3)(i).
(iii) You must comply with paragraph (h)(5) of this section within 30 days of the monthly determination according to the requirements of § 60.5396c(a)(3)(ii), where the monthly emissions determination indicates that methane emissions from your storage vessel designated facility increase to 14 tpy or greater and the increase is not associated with fracturing or refracturing of a well feeding the storage vessel designated facility.
(3) For each storage vessel designated facility or portion of a storage vessel designated facility removed from service, you must demonstrate compliance with the requirements of § 60.5396c(c)(1) or (2) by complying with paragraphs (h)(6), (7), (9), and (10) of this section.
(4) For each storage vessel designated facility or portion of a storage vessel designated facility returned to service, you must demonstrate compliance with the requirements of § 60.5396c(c)(3) and (4) by complying with paragraphs (h)(8) through (10) of this section.
(5) For each storage vessel designated facility, you must comply with paragraphs (h)(5)(i) and (ii) of this section.
(i) You must reduce methane emissions as specified in § 60.5396c(a)(2).
(ii) For each control device installed to meet the requirements of § 60.5396c(a)(2), you must demonstrate continuous compliance with the performance requirements of § 60.5412c for each storage vessel designated facility using the procedure specified in paragraph (h)(5)(ii)(A) and (B) of this section. When routing emissions to a process, you must demonstrate continuous compliance as specified in paragraph (h)(5)(ii)(A) of this section.
(A) You must comply with § 60.5416c for each cover and closed vent system.
(B) You must comply with the requirements specified in paragraph (e) of this section.
(6) You must completely empty and degas each storage vessel, such that each storage vessel no longer contains crude oil, condensate, produced water or intermediate hydrocarbon liquids. For a portion of a storage vessel designated facility to be removed from service, you must completely empty and degas the storage vessel(s), such that the storage vessel(s) no longer contains crude oil, condensate, produced water or intermediate hydrocarbon liquids. A storage vessel where liquid is left on walls, as bottom clingage or in pools due to floor irregularity is considered to be completely empty.
(7) You must disconnect the storage vessel(s) from the tank battery by isolating the storage vessel(s) from the tank battery such that the storage vessel(s) is no longer manifolded to the tank battery by liquid or vapor transfer.
(8) You must determine the designated facility status of a storage vessel returned to service as provided in § 60.5386c(e)(5).
(9) You must submit the annual reports as required by § 60.5420c(b)(1) and (7) and (b)(10)(i) through (iv).
(10) You must maintain the records as required by § 60.5420c(c)(6) through (9) and (11), as applicable.
(i) Process unit equipment designated facility. For each process unit equipment designated facility, you must demonstrate continuous compliance with the requirements of § 60.5400c according to paragraphs (i)(1) through (4) and (11) through (15) of this section, unless you meet and comply with the exception in § 60.5402c(b), (e), or (f) or meet the exemption in § 60.5402c(c). Alternatively, if you comply with the GHG standards for process unit designated facilities using the standards in § 60.5401c, you must comply with paragraphs (i)(5) through (15) of this section, unless you meet the exemption in § 60.5402c(b) or (c) or the exception in § 60.5402c(e) and (f).
(1) You must conduct monitoring for each pump in light liquid service, pressure relief device in gas/vapor service, valve in gas/vapor and light liquid service and connector in gas/vapor and light liquid service as required by § 60.5400c(b).
(2) You must conduct monitoring as required by § 60.5400c(c) for each pump in light liquid service.
(3) You must conduct monitoring as required by § 60.5400c(d) for each pressure relief device in gas/vapor service.
(4) You must comply with the equipment requirements for each open-ended valve or line as required by § 60.5400c(e).
(5) You must conduct monitoring for each pump in light liquid service as required by § 60.5401c(b).
(6) You must conduct monitoring for each pressure relief device in gas/vapor service as required by § 60.5401c(c).
(7) You must comply with the equipment requirements for each open-ended valve or line as required by § 60.5401c(d).
(8) You must conduct monitoring for each valve in gas/vapor or light liquid service as required by § 60.5401c(f).
(9) You must conduct monitoring for each pump, valve, and connector in heavy liquid service and each pressure relief device in light liquid or heavy liquid service as required by § 60.5401c(g).
(10) You must conduct monitoring for each connector in gas/vapor or light liquid service as required by § 60.5401c(h).
(11) You must collect emissions and meet the closed vent system requirements as required by § 60.5416c for each pump equipped with a dual mechanical seal system that degasses the barrier fluid reservoir to a process or a control device, each pump which captures and transports leakage from the seal or seals to a process or control device, or each pressure relief device which captures and transports leakage through the pressure relief device to a process or control device.
(12) You must comply with the requirements specified in paragraph (e) of this section.
(13) You must tag and repair each identified leak as required in § 60.5400c(h) or § 60.5401c(i), as applicable.
(14) You must submit semiannual reports as required by § 60.5422c and the annual reports in § 60.5420c(b)(10)(i) through (iv), as applicable.
(15) You must maintain the records specified by § 60.5420c(c)(7), (c)(9), and (c)(11) as applicable and § 60.5421c.
(j) Continuous compliance. For each fugitive emissions components designated facility, you must demonstrate continuous compliance with the requirements of § 60.5397c(a) according to paragraphs (j)(1) through (4) of this section.
(1) You must conduct periodic monitoring surveys as required in § 60.5397c(e) and (g).
(2) You must repair each identified source of fugitive emissions as required in § 60.5397c(h).
(3) You must submit annual reports for fugitive emissions components designated facilities as required in § 60.5420c(b)(1) and (8).
(4) You must maintain records as specified in § 60.5420c(c)(13).
60. Amend § 60.5416c by revising paragraph (a) introductory text and (a)(3)(iii) to read as follows:
What are the initial and continuous cover and closed vent system inspection and monitoring requirements?* * * * *(a) Inspections for closed vent systems, covers, and bypass devices. If you install a control device or route emissions to a process, you must inspect each closed vent system according to the procedures and schedule specified in paragraphs (a)(1) and (2) of this section, inspect each cover according to the procedures and schedule specified in paragraph (a)(3) of this section, and inspect each bypass device according to the procedures of paragraph (a)(4) of this section, except as provided in paragraphs (b)(7) and (8) of this section.
* * * * *(3) * * *
(iii) Conduct AVO inspections in accordance with and at the same frequency as specified for fugitive emissions components designated facilities located at the same type of site as specified in § 60.5397c(g). Process unit equipment designated facilities must conduct annual AVO inspections concurrent with the inspections required by paragraph (a)(1)(ii) of this section.
* * * * *61. Amend § 60.5417c by revising and republishing the introductory text and paragraphs (a), (d)(8) introductory text, and (d)(8)(iii) to read as follows:
What are the continuous monitoring requirements for my control devices?You must meet the requirements of this section to demonstrate continuous compliance for each control device used to meet emission standards for your well, centrifugal compressor, reciprocating compressor, process controller, pump, storage vessel, and process unit equipment designated facilities.
(a) For each control device used to comply with the emission reduction standard in § 60.5391c(b) for well designated facilities, § 60.5392c(a)(3) for centrifugal compressor designated facilities, § 60.5393c(d)(2) for reciprocating compressor designated facilities, § 60.5394c(b)(3) for your process controller designated facility in Alaska, § 60.5395c(b)(1) for your pumps designated facility, § 60.5396c(a)(2) for your storage vessel designated facility, or either § 60.5400c(f) or § 60.5401c(e) for your process equipment designated facility, you must install and operate a continuous parameter monitoring system for each control device as specified in paragraphs (c) through (h) of this section, except as provided for in paragraph (b) of this section. If you install and operate a flare in accordance with § 60.5412c(a)(3), you are exempt from the requirements of paragraph (f) of this section. If you operate an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d), you must operate the control device as specified in paragraph (i) of this section instead of using the procedures specified in paragraphs (c) through (h) of this section. You must keep records and report in accordance with paragraph (j) of this section.
* * * * *(d) * * *
(8) For an enclosed combustion device, other than those listed in paragraphs (d)(1) through (3) and (7) of this section, or for a flare, continuous monitoring systems as specified in paragraphs (d)(8)(i) through (iv) of this section and visible emission observations conducted as specified in paragraph (d)(8)(v) of this section. Additionally, for enclosed combustion devices or flares that are air-assisted or steam-assisted, the continuous monitoring systems specified in paragraph (d)(8)(vi) of this section.
* * * * *(iii) For an unassisted or pressure-assisted flare or enclosed combustion device, if you demonstrate according to the methods described in paragraphs (d)(8)(iii)(A) through (F) of this section that the NHV of the inlet gas to the enclosed combustion device or flare consistently exceeds the applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), continuous monitoring of the NHV is not required, but you must conduct the ongoing sampling in paragraph (d)(8)(iii)(G) of this section. For flares and enclosed combustion devices that use only perimeter assist air and do not use steam assist or premix assist air, if you demonstrate according to the methods described in paragraphs (d)(8)(iii)(A) through (F) of this section that the NHV of the inlet gas to the enclosed combustion device or flare consistently exceeds 300 Btu/scf, continuous monitoring of the NHV is not required, but you must conduct the ongoing sampling in paragraph (d)(8)(iii)(G) of this section. For an unassisted or pressure-assisted flare or enclosed combustion device, in lieu of conducting the demonstration outlined in paragraphs (d)(8)(iii)(A) through (D) of this section, you may conduct the demonstration outlined in paragraph (d)(8)(iii)(H) of this section, but you must still comply with paragraphs (d)(8)(iii)(E) through (G) of this section.
(A) Continuously monitor or collect a sample of the inlet gas to the enclosed combustion device or flare twice daily to determine the average NHV of the gas stream for 14 consecutive operating days. If you do not continuously monitor the NHV, the minimum time of collection for each individual sample be at least one hour. Consecutive samples must be separated by at least 6 hours. If inlet gas flow is intermittent such that there are not at least 28 samples over the 14 operating day period, you must continue to collect samples of the inlet gas beyond the 14 operating day period until you collect a minimum of 28 samples.
(B) If you collect samples twice per day, count the number of samples where the NHV value is less than 1.2 times the applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii) ( i.e., values that are less than 240, 360, or 960 Btu/scf, as applicable) during the sample collection period in paragraph (d)(8)(iii)(A) of this section.
(C) If you continuously sample the inlet stream for 14 days, count the number of hourly average NHV values that are less than the applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii) ( i.e., values that are less than 200, 300, or 800 Btu/scf, as applicable), during the sample collection period in paragraph (d)(8)(iii)(A) of this section.
(D) If there are no samples counted under paragraph (d)(8)(iii)(B) of this section or there are no hourly values counted under paragraph (d)(8)(iii)(C) of this section, the gas stream is considered to consistently exceed the applicable NHV operating limit and on-going continuous monitoring is not required.
(E) If process operations are revised that could impact the NHV of the gas sent to the enclosed combustion device or flare, such as the removal or addition of process equipment, and at any time the Administrator requires, re-evaluation of the gas stream must be performed according to paragraphs (d)(8)(iii)(A) through (D) of this section to ensure the gas stream still consistently exceeds the applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii).
(F) When collecting samples under paragraph (d)(8)(iii)(A) of this section, the owner or operator must account for any sources of inert gases that can be sent to the enclosed combustion device or flare ( e.g., streams from compressors in acid gas service, streams from enhanced oil recovery facilities). The report in § 60.5420c(b)(10)(v)(I) and the records of the demonstration in § 60.5420c(c)(10)(vi) must note whether the enclosed combustion device or flare has the potential to receive inert gases, and if so, whether the sampling included periods where the highest percentage of inert gases were sent to the enclosed combustion device or flare. If the introduction of inerts is intermittent and does not occur during the initial demonstration, the introduction of inerts will be considered a revision to process operations that triggers a re-evaluation under paragraph (d)(8)(iii)(E) of this section. If conditions at the site did not allow sampling during periods where the introduction of inert gases was at the highest percentage possible, increasing the percentage of inerts will be considered a revision to process operations that triggers a re-evaluation under paragraph (d)(8)(iii)(E) of this section.
(G) You must collect three samples of the inlet gas to the enclosed combustion device or flare at least once every 5 years. The minimum time of collection for each individual sample must be at least one hour. The samples must be taken during the period with the lowest expected NHV ( i.e., the period with the highest percentage of inerts). The first set of periodic samples must be taken, or continuous monitoring commenced, no later than 60 calendar months following the last sample taken under paragraph (d)(8)(iii)(A) of this section. Subsequent periodic samples must be taken, or continuous monitoring commenced, no later than 60 calendar months following the previous sample. If any sample has an NHV value less than 1.2 times the applicable operating limit specified in § 60.5415c(e)(1)(vii)(B) or (C), or this paragraph (d)(8)(iii) ( i.e., values that are less than 240, 360, or 960 Btu/scf, as applicable), you must conduct the monitoring required by paragraph (d)(8)(ii) of this section.
(H) You may request an alternative test method under § 60.5412c(d) to demonstrate that the flare or enclosed combustion device reduces methane and VOC in the gases vented to the device by 95.0 percent by weight or greater. You must use an alternative test method that demonstrates compliance with the combustion efficiency limit; you may not use an alternative test method that demonstrates compliance with NHVcz and NHVdil in lieu of measuring combustion efficiency directly. You must measure data values at the frequency specified in the alternative test method and conduct the quality assurance and quality control requirements outlined in the alternative test method at the frequency outlined in the alternative test method. You must monitor the combustion efficiency of the flare continuously for 14 days. If there are no values of the combustion efficiency measured by the alternative test method that are less than 95.0 percent, the gas stream is considered to consistently exceed the applicable NHV operating limit, and you are not required to continuously monitor the NHV of the inlet gas to the flare or enclosed combustion device.
* * * * *62. Amend § 60.5420c by revising and republishing paragraphs (a) through (c) and paragraph (d) introductory text to read as follows:
What are my notification, reporting, and recordkeeping requirements?(a) Notifications. You must submit notifications according to paragraphs (a)(1) and (2) of this section if you own or operate one or more of the designated facilities specified in § 60.5386c for which you commenced construction, modification, or reconstruction on or before December 6, 2022. You must submit the notification in paragraph (a)(3) of this section if you undertake well closure activities as specified in § 60.5397c(l).
(1) Notification of compliance report. For each designated facility subject to the requirements specified under this subpart, an owner or operator is required to submit a statement of compliance with the applicable requirements of this subpart on or before 60 days after the state plan compliance date. Where a designated facility's compliance status is consistent with what was specified in the final compliance plan increment of progress report, the notification of compliance report would include a statement indicating that compliance is consistent with what was specified in the designated facility's final compliance plan. Where a designated facility's compliance status differs from what was specified in the final compliance plan increment of progress report, the notification of compliance report would indicate how the designated facility's status differs from what was stated in the final compliance plan.
(2) Notifications. If you own or operate a process unit equipment designated facility located at an onshore natural gas processing plant, you must submit the notifications required in §§ 60.7(a)(1), (3), and (4) and 60.15(d). If you own or operate a well, centrifugal compressor, reciprocating compressor, process controller, pump, storage vessel, collection of fugitive emissions components at a well site, or collection of fugitive emissions components at a compressor station designated facility, you are not required to submit the notifications required in §§ 60.7(a)(1), (3), and (4) and 60.15(d).
(3) Notification to Administrator. An owner or operator who commences well closure activities must submit the following notices to the Administrator according to the schedule in paragraph (a)(3)(i) and (ii) of this section. The notification shall include contact information for the owner or operator; the United States Well Number; the latitude and longitude coordinates for each well at the well site in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983. You must submit notifications in portable document format (PDF) following the procedures specified in paragraph (d) of this section.
(i) You must submit a well closure plan to the Administrator within 30 days of the cessation of production from all wells located at the well site.
(ii) You must submit a notification of the intent to close a well site 60 days before you begin well closure activities.
(b) Reporting requirements. You must submit annual reports containing the information specified in paragraphs (b)(1) through (13) of this section following the procedure specified in paragraph (b)(14) of this section. You must submit performance test reports as specified in paragraph (b)(11) or (12) of this section, if applicable. The initial annual report is due no later than 90 days after the end of the initial compliance period as determined according to § 60.5410c. 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 designated facility, you may submit one report for multiple designated facilities provided the report contains all of the information required as specified in paragraphs (b)(1) through (13) of this section. 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. You must submit the information in paragraph (b)(1)(v) of this section, as applicable, for your well designated facility which undergoes a change of ownership during the reporting period, regardless of whether reporting under (b)(2) through (3) of this section is required for the well designated facility.
(1) The general information specified in paragraphs (b)(1)(i) through (v) of this section is required for all reports.
(i) The company name, facility site name associated with the designated facility, U.S. Well ID or U.S. Well ID associated with the designated facility, if applicable, and address of the designated 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 and precision of five (5) decimals of a degree using the North American Datum of 1983.
(ii) An identification of each designated facility being included in the annual report.
(iii) Beginning and ending dates of the reporting period.
(iv) 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 (b)(1)(iv).
(v) Identification of each well designated facility for which ownership changed due to sale or transfer of ownership including the United States Well Number; the latitude and longitude coordinates of the well designated facility in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983; and the information in paragraph (b)(1)(v)(A) or (B) of this section, as applicable.
(A) The name and contact information, including the phone number, email address, and mailing address, of the owner or operator to which you sold or transferred ownership of the well designated facility identified in paragraph (b)(1)(v) of this section.
(B) The name and contact information, including the phone number, email address, and mailing address, of the owner or operator from whom you acquired the well designated facility identified in paragraph (b)(1)(v) of this section.
(2) For each well designated facility that is subject to § 60.5390c(a)(1) or (2), your annual report is required to include the information specified in paragraphs (b)(2)(i) and (ii) of this section, as applicable.
(i) For each well designated facility where all gas well liquids unloading operations comply with § 60.5390c(a)(1), your annual report must include the information specified in paragraphs (b)(2)(i)(A) through (C) of this section, as applicable.
(A) Identification of each well designated facility (U.S. Well ID or U.S. Well ID associated with the well designated facility) that conducts a gas well liquid unloading operation during the reporting period using a method that does not vent to the atmosphere and the technology or technique used. If more than one non-venting technology or technique is used, you must identify all of the differing non-venting liquids unloading methods used during the reporting period.
(B) Number of gas well liquids unloading operations conducted during the year where the well designated facility identified in (b)(2)(i)(A) had unplanned venting to the atmosphere and best management practices were conducted according to your best management practice plan, as required by § 60.5390c(c). If no venting events occurred, the number would be zero. Other reported information required to be submitted where unplanned venting occurs is specified in paragraphs (b)(2)(i)(B)( 1) and ( 2) of this section.
( 1) Log of best management practice plan steps used during the unplanned venting to minimize emissions to the maximum extent possible.
( 2) The number of liquids unloading events during the year where deviations from your best management practice plan occurred, the date and time the deviation began, the duration of the deviation in hours, documentation of why best management practice plan steps were not followed, and what steps, in lieu of your best management practice plan steps, were followed to minimize emissions to the maximum extent possible.
(C) The number of liquids unloading events where unplanned emissions are vented to the atmosphere during a gas well liquids unloading operation where you complied with best management practices to minimize emissions to the maximum extent possible.
(ii) For each well designated facility where all gas well liquids unloading operations comply with § 60.5390c(b) and (c) best management practices, your annual report must include the information specified in paragraphs (b)(2)(ii)(A) through (E) of this section.
(A) Identification of each well designated facility that conducts a gas well liquids unloading during the reporting period.
(B) Number of liquids unloading events conducted during the reporting period.
(C) Log of best management practice plan steps used during the reporting period to minimize emissions to the maximum extent possible.
(D) The number of liquids unloading events during the year that best management practices were conducted according to your best management practice plan.
(E) The number of liquids unloading events during the year where deviations from your best management practice plan occurred, the date and time the deviation began, the duration of the deviation in hours, documentation of why best management practice plan steps were not followed, and what steps, in lieu of your best management practice plan steps, were followed to minimize emissions to the maximum extent possible.
(3) For each associated gas well at your well designated facility that is subject to § 60.5391c, your annual report is required to include the applicable information specified in paragraphs (b)(3)(i) through (v) of this section, as applicable.
(i) For each associated gas well at your well designated facility that complies with § 60.5391c(a)(1), (2), (3), or (4) your annual report is required to include the information specified in paragraphs (b)(3)(i)(A) and (B) of this section.
(A) An identification of each existing associated gas well that complies with § 60.5391c(a)(1), (2), (3), or (4).
(B) The information specified in paragraphs (b)(3)(i)(B)( 1) through ( 3) of this section for each incident when the associated gas was temporarily routed to a flare or control device in accordance with § 60.5391c(c).
( 1) The reason in § 60.5391c(c)(1), (2), (3), or (4) for each incident.
( 2) The start date and time of each incident of routing associated gas to the flare or control device, along with the total duration in hours of each incident.
( 3) Documentation that all CVS requirements specified in § 60.5411c(a) and (c) and all applicable flare or control device requirements specified in § 60.5412c were met during each period when the associated gas is routed to the flare or control device.
(ii) For all instances where you temporarily vent the associated gas in accordance with § 60.5391c(d), you must report the information specified in paragraphs (b)(3)(ii)(A) through (D) of this section. This information is required to be reported if you are routinely complying with § 60.5391c(a) or § 60.5391c(b) or temporarily complying with § 60.5391c(c). In addition to this information for each incident, you must report the cumulative duration in hours of venting incidents and the cumulative VOC and methane emissions in pounds for all incidents in the calendar year.
(A) The reason in § 60.5391c(d)(1), (2), or (3) for each incident.
(B) The start date and time of each incident of venting the associated gas, along with the total duration in hours of each incident.
(C) The methane emissions in pounds that were emitted during each incident.
(D) The total duration of venting for all incidents in the year, along with the cumulative methane emissions in pounds that were emitted.
(iii) For each associated gas well at your well designated facility that complies with the requirements of § 60.5391c(b) by routing your associated gas to a control device that reduces methane emissions by at least 95.0 percent, your annual report must include the information specified in paragraphs (b)(3)(iii)(A) through (C) of this section, and paragraph (D) or (E) of this section. The information in paragraphs (b)(3)(iii)(A) and (B) of this section is only required in the initial annual report.
(A) Identification of the associated gas well using the control device and the information in paragraphs (b)(10)(v) of this section.
(B) The information specified in paragraphs (b)(10)(i) through (iv) of this section.
(C) Identification of each instance when associated gas was vented and not routed to a control device that reduces methane emissions by at least 95.0 percent in accordance with paragraph (b)(3)(ii) of this section.
(D) For each associated gas well that complies with the requirements of § 60.5391c(b) because it has demonstrated that annual methane emissions are 40 tons per year or less, provide records of the calculation of annual methane emissions determined in accordance with § 60.5391c(e)(1).
(E) For each associated gas well facility that complies with the requirements of § 60.5391c(b) because it has demonstrated that it is not feasible to comply with § 60.5391c(a)(1), (2), (3), or (4) due to technical reasons, provide each annual demonstration and certification of the technical reason that it is not feasible to comply with § 60.5391c(a)(1), (2), (3), and (4) in accordance with § 60.5391c(b)(2)(i), (ii), and (iii).
(iv) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(v) For each deviation recorded as specified in paragraph (c)(2)(vi) of this section, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(4) For each centrifugal compressor that is a designated facility, the information specified in paragraphs (b)(4)(i) through (ix) of this section, as applicable.
(i) An identification of each centrifugal compressor.
(ii) For each deviation that occurred during the reporting period and recorded as specified in paragraph (c)(3) of this section, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(iii) If complying with § 60.5392c(a)(1) and (2) wet and dry seal centrifugal compressor requirements, the cumulative number of hours of operation since initial startup, since 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), or since the previous volumetric flow rate measurement, as applicable, which have elapsed prior to conducting your volumetric flow rate measurement or emissions screening.
(iv) A description of the method used and the results of the volumetric emissions measurement or emissions screening, as applicable.
(v) If required to comply with § 60.5392c(a)(5), the information specified in paragraphs (b)(10)(i) through (iv) of this section.
(vi) If complying with § 60.5392c(a)(4) with a control device, identification of the centrifugal compressor with the control device and the information in paragraph (b)(10)(v) of this section.
(vii) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(viii) Number and type of seals on delay of repair and explanation for each delay of repair.
(ix) Date of planned shutdown(s) that occurred during the reporting period if there are any seals that have been placed on delay of repair.
(5) For each reciprocating compressor designated facility, the information specified in paragraphs (b)(5)(i) through (vii) of this section, as applicable.
(i) The cumulative number of hours of operation since initial startup, since 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), since the previous volumetric flow rate measurement, or since the previous reciprocating compressor rod packing replacement, as applicable, which have elapsed prior to conducting your volumetric flow rate measurement or emissions screening. Alternatively, a statement that emissions from the rod packing are being routed to a process or control device through a closed vent system.
(ii) If applicable, for each deviation that occurred during the reporting period and recorded as specified in paragraph (c)(4)(i) of this section, the date and time the deviation began, duration of the deviation in hours and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(iii) A description of the method used and the results of the volumetric flow rate measurement or emissions screening, as applicable.
(iv) If complying with § 60.5393c(d)(1) or (2), the information in paragraphs (b)(10)(i) through (v) of this section.
(v) Number and type of rod packing replacements/repairs on delay of repair and explanation for each delay of repair.
(vi) Date of planned shutdown(s) that occurred during the reporting period if there are any rod packing replacements/repairs that have been placed on delay of repair.
(vii) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(6) For each process controller designated facility, the information specified in paragraphs (b)(6)(i) through (iii) of this section in your initial annual report and in subsequent annual reports for each process controller designated facility that is constructed, modified, or reconstructed during the reporting period. Each annual report must contain the information specified in paragraphs (b)(6)(iv) through (x) of this section for each process controller designated facility.
(i) An identification of each existing process controller that is driven by natural gas, as required by § 60.5394c(d), that allows traceability to the records required in paragraph (c)(5)(i) of this section.
(ii) For each process controller in the designated facility complying with § 60.5394c(a), you must report the information specified in paragraphs (b)(6)(ii)(A) and (B) of this section, as applicable.
(A) An identification of each process controller complying with § 60.5394c(a)(1) by routing the emissions to a process.
(B) An identification of each process controller complying with § 60.5394c(a)(2) by using a self-contained natural gas-driven process controller.
(iii) For each process controller designated facility located at a site in Alaska that does not have access to electrical power and that complies with § 60.5394c(b), you must report the information specified in paragraphs (b)(6)(iii)(A), (B), or (C) of this section, as applicable.
(A) For each process controller complying with § 60.5394c(b)(1) process controller bleed rate requirements, you must report the information specified in paragraphs (b)(6)(iii)(A)( 1) and ( 2) of this section.
( 1) The identification of process controllers designed and operated to achieve a bleed rate less than or equal to 6 scfh.
( 2) Where necessary to meet a functional need, the identification and demonstration of why it is necessary to use a process controller with a natural gas bleed rate greater than 6 scfh.
(B) An identification of each intermittent vent process controller complying with the requirements in paragraph § 60.5394c(b)(2).
(C) An identification of each process controller complying with the requirements in § 60.5394c(b) by routing emissions to a control device in accordance with § 60.5394c(b)(3).
(iv) Identification of each process controller which changes its method of compliance during the reporting period and the applicable information specified in paragraphs (b)(6)(v) through (ix) of this section for the new method of compliance.
(v) For each process controller in the designated facility complying with the requirements of § 60.5394c(a) by routing the emissions to a process, you must report the information specified in paragraphs (b)(10)(i) through (iv) of this section.
(vi) For each process controller in the designated facility complying with the requirements of § 60.5394c(a) by using a self-contained natural gas-driven process controller, you must report the information specified in paragraphs (b)(6)(vi)(A) and (B) of this section.
(A) Dates of each inspection required under § 60.5416c(b); and
(B) Each defect or leak identified during each natural gas-driven-self-contained process controller system inspection, and the date of repair or date of anticipated repair if repair is delayed.
(vii) For each process controller in the designated facility complying with the requirements of § 60.5394c(b)(2), you must report the information specified in paragraphs (b)(6)(vii)(A) and (B) of this section.
(A) Dates and results of the intermittent vent process controller monitoring required by § 60.5394c(b)(2)(ii).
(B) For each instance in which monitoring identifies emissions to the atmosphere from an intermittent vent controller during idle periods, the date of repair or replacement or the date of anticipated repair or replacement if the repair or replacement is delayed, and the date and results of the re-survey after repair or replacement.
(viii) For each process controller designated facility complying with § 60.5394c(b)(3) by routing emissions to a control device, you must report the information specified in paragraph (b)(10) of this section.
(ix) For each deviation that occurred during the reporting period, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(x) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(6)(ii)(B) and (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(7) For each storage vessel designated facility, the information in paragraphs (b)(7)(i) through (x) of this section.
(i) An identification, including the location, of each existing storage vessel designated facility. The location of the storage vessel designated facility shall be in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983.
(ii) Documentation of the methane emission rate determination according to § 60.5386c(e)(1) for each tank battery that became a designated facility during the reporting period or is returned to service during the reporting period.
(iii) For each deviation that occurred during the reporting period and recorded as specified in paragraph (c)(6)(iii) of this section, the date and time the deviation began, duration of the deviation in hours and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(iv) For each storage vessel designated facility complying with § 60.5396c(a)(2) with a control device, report the identification of the storage vessel designated facility with the control device and the information in paragraph (b)(10)(v) of this section.
(v) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(vi) If required to comply with § 60.5396c(b)(1), the information in paragraphs (b)(10)(i) through (iv) of this section.
(vii) You must identify each storage vessel designated facility that is removed from service during the reporting period as specified in § 60.5396c(c)(1)(ii), including the date the storage vessel designated facility was removed from service. You must identify each storage vessel that that is removed from service from a storage vessel designated facility during the reporting period as specified in § 60.5396c(c)(2)(iii), including identifying the impacted storage vessel designated facility and the date each storage vessel was removed from service.
(viii) You must identify each storage vessel designated facility or portion of a storage vessel designated facility returned to service during the reporting period as specified in § 60.5396c(c)(4), including the date the storage vessel designated facility or portion of a storage vessel designated facility was returned to service.
(ix) You must identify each storage vessel designated facility that no longer complies with § 60.5396c(a)(3) and instead complies with § 60.5396c(a)(2). You must identify whether the change in the method of compliance was due to fracturing or refracturing or whether the change was due to an increase in the monthly emissions determination. If the change was due to an increase in the monthly emissions determination, you must provide documentation of the emissions rate. You must identify the date that you complied with § 60.5396c(a)(2) and must submit the information in (b)(7)(iii) through (vii) of this section.
(x) You must submit a statement that you are complying with § 60.112b(a)(1) or (2), if applicable, in your initial annual report.
(8) For the fugitive emissions components designated facility, report the information specified in paragraphs (b)(8)(i) through (iv) of this section, as applicable.
(i)(A) Designation of the type of site ( i.e., well site, centralized production facility, or compressor station) at which the fugitive emissions components designated facility is located.
(B) For the fugitive emissions components designated facility at a well site or centralized production facility that became a designated facility during the reporting period, you must include the date of the startup of production or the date of the first day of production after modification. For the fugitive emissions components designated facility at a compressor station that became a designated facility during the reporting period, you must include the date of startup or the date of modification.
(C) For the fugitive emissions components designated facility at a well site, you must specify what type of well site it is ( i.e., single wellhead only well site, small wellsite, multi-wellhead only well site, or a well site with major production and processing equipment).
(D) For the fugitive emissions components designated facility at a well site where during the reporting period you complete the removal of all major production and processing equipment such that the well site contains only one or more wellheads, you must include the date of the change to status as a wellhead only well site.
(E) For the fugitive emissions components designated facility at a well site where you previously reported under paragraph (b)(8)(i)(D) of this section the removal of all major production and processing equipment and during the reporting period major production and processing equipment is added back to the well site, the date that the first piece of major production and processing equipment is added back to the well site.
(F) For the fugitive emissions components designated facility at a well site where during the reporting period you undertake well closure requirements, the date of the cessation of production from all wells at the well site, the date you began well closure activities at the well site, and the dates of the notifications submitted in accordance with paragraph (a)(3) of this section.
(ii) For each fugitive emissions monitoring survey performed during the annual reporting period, the information specified in paragraphs (b)(8)(ii)(A) through (G) of this section.
(A) Date of the survey.
(B) Monitoring instrument or, if the survey was conducted by visual, audible, or olfactory methods, notation that AVO was used.
(C) Any deviations from the monitoring plan elements under § 60.5397c(c)(1), (2), (7), and (8) or (d) or a statement that there were no deviations from these elements of the monitoring plan.
(D) Number and type of components for which fugitive emissions were detected.
(E) Number and type of fugitive emissions components that were not repaired as required in § 60.5397c(h).
(F) Number and type of fugitive emission components (including designation as difficult-to-monitor or unsafe-to-monitor, if applicable) on delay of repair and explanation for each delay of repair.
(G) Date of planned shutdown(s) that occurred during the reporting period if there are any components that have been placed on delay of repair.
(iii) For well closure activities which occurred during the reporting period, the information in paragraphs (b)(8)(iii)(A) and (B) of this section.
(A) A status report with dates for the well closure activities schedule developed in the well closure plan. If all steps in the well closure plan are completed in the reporting period, the date that all activities are completed.
(B) If an OGI survey is conducted during the reporting period, the information in paragraphs (b)(8)(iii)(B)( 1) through ( 3) of this section.
( 1) Date of the OGI survey.
( 2) Monitoring instrument used.
( 3) A statement that no fugitive emissions were found, or if fugitive emissions were found, a description of the steps taken to eliminate those emissions, the date of the resurvey, the results of the resurvey, and the date of the final resurvey which detected no emissions.
(iv) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(9) For each pump designated facility, the information specified in paragraphs (b)(9)(i) through (iv) of this section in your initial annual report. Each annual report must contain the information specified in paragraphs (b)(9)(v) through (ix) of this section for each pump designated facility.
(i) The identification of each of your pumps that are driven by natural gas, as required by § 60.5395c(a) that allows traceability to the records required by paragraph (c)(14)(i) of this section.
(ii) For each pump designated facility for which there is a control device on site but it does not achieve a 95.0 percent emissions reduction, the certification that there is a control device available on site but it does not achieve a 95.0 percent emissions reduction required under § 60.5395c(b)(5). You must also report the emissions reduction percentage the control device is designed to achieve.
(iii) For each pump designated facility for which there is no control device or vapor recovery unit on site, the certification required under § 60.5395c(b)(6) that there is no control device or vapor recovery unit on site.
(iv) For each pump designated facility for which it is technically infeasible to route the emissions to a process or control device, the certification of technically infeasibility required under § 60.5395c(b)(7).
(v) For any pump designated facility which has previously reported as required under paragraphs (b)(9)(i) through (iv) of this section and for which a change in the reported condition has occurred during the reporting period, provide the identification of the pump designated facility and the date that the pump designated facility meets one of the change conditions described in paragraphs (b)(9)(v)(A) through (C) of this section.
(A) If you install a control device or vapor recovery unit, you must report that a control device or vapor recovery unit has been added to the site and that the pump designated facility now is required to comply with § 60.5395c(b)(1) or (3), as applicable.
(B) If your pump designated facility previously complied with § 60.5395c(b)(1) or (3), as applicable, by routing emissions to a process or a control device and the process or control device is subsequently removed from the site or is no longer available such that there is no ability to route the emissions to a process or control device at the location, or that it is not technically feasible to capture and route the emissions to another control device or process located on site, report that you are no longer complying with the applicable requirements of § 60.5395c(b)(1) or (3) and submit the information provided in paragraphs (b)(9)(v)(B)( 1) or ( 2) of this section.
( 1) Certification that there is no control device or vapor recovery unit on site.
( 2) Certification of the engineering assessment that it is technically infeasible to capture and route the emissions to another control device or process located on site.
(C) If any pump affected facility or individual natural gas-driven pump changes its method of compliance during the reporting period other than for the reasons specified in paragraphs (b)(9)(v)(A) and (B) of this section, identify the new compliance method for each natural gas-driven pump within the affected facility which changes its method of compliance during the reporting period and provide the applicable information specified in paragraphs (b)(9)(ii) through (iv) and (vi) through (viii) of this section for the new method of compliance.
(vi) For each pump designated facility complying with the requirements of § 60.5395c(a) or (b)(2) by routing the emissions to a process, you must report the information specified in paragraphs (b)(10)(i) through (iv) of this section.
(vii) For each pump designated facility complying with the requirements of § 60.5395c(b)(3) by routing the emissions to a control device, you must report the information required under paragraph (b)(10) of this section.
(viii) For each deviation that occurred during the reporting period, the date and time the deviation began, the duration of the deviation in hours, and a description of the deviation. If no deviations occurred during the reporting period, you must include a statement that no deviations occurred during the reporting period.
(ix) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (b)(10)(i) and (ii) of this section, you must provide the information specified in § 60.5424c.
(10) For each well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment designated facility which uses a closed vent system routed to a control device to meet the emissions reduction standard, you must submit the information in paragraphs (b)(10)(i) through (v) of this section. For each centrifugal compressor, reciprocating compressor, process controller, pump, storage vessel, or process unit equipment which uses a closed vent system to route to a process, you must submit the information in paragraphs (b)(10)(i) through (iv) of this section. For each centrifugal compressor, reciprocating compressor, and storage vessel equipped with a cover, you must submit the information in paragraphs (b)(10)(i) and (ii).
(i) Dates of each inspection required under § 60.5416c(a) and (b).
(ii) Each defect or emissions identified during each inspection and the date of repair or the date of anticipated repair if the repair is delayed.
(iii) Date and time of each bypass alarm or each instance the key is checked out if you are subject to the bypass requirements of § 60.5416c(a)(4).
(iv) You must submit the certification signed by the qualified professional engineer or in-house engineer according to § 60.5411c(c) for each closed vent system routing to a control device or process in the reporting year in which the certification is signed.
(v) If you comply with the emissions standard for your well, centrifugal compressor, reciprocating compressor, storage vessel, process controller, pump, or process unit equipment designated facility with a control device, the information in paragraphs (b)(10)(v)(A) through (L) of this section, unless you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d). If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d), the information in paragraphs (b)(10)(v)(A) through (C) and (L) through (P) of this section.
(A) Identification of the control device.
(B) Make, model, and date of installation of the control device.
(C) Identification of the designated facility controlled by the device.
(D) For each continuous parameter monitoring system used to demonstrate compliance for the control device, a unique continuous parameter monitoring system identifier and the make, model number, and date of last calibration check of the continuous parameter monitoring system.
(E) For each instance where there is a deviation of the control device in accordance with § 60.5417c(g)(1) through (3) or (5) through (7) include the date and time the deviation began, the duration of the deviation in hours, the type of the deviation ( e.g., NHV operating limit, lack of pilot or combustion flame, condenser efficiency, bypass line flow, visible emissions), and cause of the deviation.
(F) For each instance where there is a deviation of the continuous parameter monitoring system in accordance with § 60.5417c(g)(4) include the date and time the deviation began, the duration of the deviation in hours, and cause of the deviation.
(G) For each visible emissions test following return to operation from a maintenance or repair activity, the date of the visible emissions test or observation of the video surveillance output, the length of the observation in minutes, and the number of minutes for which visible emissions were present.
(H) If a performance test was conducted on the control device during the reporting period, provide the date the performance test was conducted. Submit the performance test report following the procedures specified in paragraph (b)(11) of this section.
(I) If a demonstration of the NHV of the inlet gas to the enclosed combustion device or flare was conducted during the reporting period in accordance with § 60.5417c(d)(8)(iii), an indication of whether this is a re-evaluation of vent gas NHV and the reason for the re-evaluation; the applicable required minimum vent gas NHV; if twice daily samples of the vent stream were taken, the number of hourly average NHV values that are less than 1.2 times the applicable required minimum NHV; if continuous NHV sampling of the vent stream was conducted, the number of hourly average NHV values that are less than the required minimum vent gas NHV; if continuous combustion efficiency monitoring was conducted using an alternative test method approved under § 60.5412c(d), the number of values of the combustion efficiency that were less than 95.0 percent; the resulting determination of whether NHV monitoring is required or not in accordance with § 60.5417c(d)(8)(iii)(D) or (H); and an indication of whether the enclosed combustion device or flare has the potential to receive inert gases, and if so, whether the sampling included periods where the highest percentage of inert gases were sent to the enclosed combustion device or flare.
(J) If a demonstration was conducted in accordance with § 60.5417c(d)(8)(iv) that the maximum potential pressure of units manifolded to an enclosed combustion device or flare cannot cause the maximum inlet flow rate established in accordance with § 60.5417c(f)(1) or a flare tip velocity limit of 18.3 meter/second (60 feet/second) to be exceeded, an indication of whether this is a re-evaluation of the gas flow and the reason for the re-evaluation; the demonstration conducted; and applicable engineering calculations.
(K) For each periodic sampling event conducted under § 60.5417c(d)(8)(iii)(G), provide the date of the sampling, the required minimum vent gas NHV, and the NHV value for each vent gas sample.
(L) For each flare and enclosed combustion device, provide the date each device is observed with OGI in accordance with § 60.5415c(e)(1)(x) and whether uncombusted emissions were present. Provide the date each device was visibly observed during an AVO inspection in accordance with § 60.5415c(e)(1)(x), whether the pilot or combustion flame was lit at the time of observation, and whether the device was found to be operating properly.
(M) An identification of the alternative test method used.
(N) For each instance where there is a deviation of the control device in accordance with § 60.5417c(i)(6)(i) or (iii) through (v) include the date and time the deviation began, the duration of the deviation in hours, the type of the deviation ( e.g., NHVcz operating limit, lack of pilot or combustion flame, visible emissions), and cause of the deviation.
(O) For each instance where there is a deviation of the data availability in accordance with § 60.5417c(i)(6)(ii) include the date of each operating day when monitoring data are not available for at least 75 percent of the operating hours.
(P) If no deviations occurred under paragraph (b)(10)(v)(N) or (O) of this section, a statement that there were no deviations for the control device during the annual report period.
(Q) Any additional information required to be reported as specified by the Administrator as part of the alternative test method approval under § 60.5412c(d).
(11) Within 60 days after the date of completing each performance test (see § 60.8) required by this subpart, except testing conducted by the manufacturer as specified in § 60.5413c(d), you must submit the results of the performance test following the procedures specified in paragraph (d) of this section. Data collected using test methods that are supported by the EPA's Electronic Reporting Tool (ERT) as listed on the EPA's ERT website ( https://www.epa.gov/electronic-reporting-air-emissions/electronic-reporting-tool-ert) at the time of the test must be submitted in a file format generated using the EPA's ERT. Alternatively, you may submit an electronic file consistent with the extensible markup language (XML) schema listed on the EPA's ERT website. Data collected using test methods that are not supported by the EPA's ERT as listed on the EPA's ERT website at the time of the test must be included as an attachment in the ERT or alternate electronic file.
(12) For combustion control devices tested by the manufacturer in accordance with § 60.5413c(d), an electronic copy of the performance test results required by § 60.5413c(d) shall be submitted via email to Oil__and__Gas__PT@EPA.GOV unless the test results for that model of combustion control device are posted at the following website: https://www.epa.gov/controlling-air-pollution-oil-and-natural-gas-industry.
(13) 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 designated facility associated with the super-emitter event, if applicable.
(14) 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 following the procedure specified in paragraph (d) of this section. 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.
(c) Recordkeeping requirements. You must maintain the records identified as specified in § 60.7(f) and in paragraphs (c)(1) through (14) of this section. 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.
(1) For each gas well liquids unloading operation at your well designated facility that is subject to § 60.5390c(a)(1) or (2), the records of each gas well liquids unloading operation conducted during the reporting period, including the information specified in paragraphs (c)(1)(i) through (iii) of this section, as applicable.
(i) For each gas well liquids unloading operation that complies with § 60.5390c(a)(1) by performing all liquids unloading events without venting of methane emissions to the atmosphere, comply with the recordkeeping requirements specified in paragraphs (c)(1)(i)(A) and (B) of this section.
(A) Identification of each well ( i.e., U.S. Well ID or U.S. Well ID associated with the well designated facility) that conducts a gas well liquids unloading operation during the reporting period without venting of methane emissions and the non-venting gas well liquids unloading method used. If more than one non-venting method is used, you must maintain records of all the differing non-venting liquids unloading methods used at the well designated facility complying with § 60.5390c(a)(1).
(B) Number of events where unplanned emissions are vented to the atmosphere during a gas well liquids unloading operation where you complied with best management practices to minimize emissions to the maximum extent possible.
(ii) For each gas well liquids unloading operation that complies with § 60.5390c(b) and (c) best management practices, maintain records documenting information specified in paragraphs (c)(1)(ii)(A) through (D) of this section.
(A) Identification of each well designated facility that conducts liquids unloading during the reporting period that employs best management practices to minimize emissions to the maximum extent possible.
(B) Documentation of your best management practice plan developed under paragraph § 60.5390c(c). You may update your best management practice plan to include additional steps which meet the criteria in § 60.5390c(c).
(C) A log of each best management practice plan step taken to minimize emissions to the maximum extent possible for each gas well liquids unloading event.
(D) Documentation of each gas well liquids unloading event where deviations from your best management practice plan steps occurred, the date and time the deviation began, the duration of the deviation, documentation of best management practice plans steps were not followed, and the steps taken in lieu of your best management practice plan steps during those events to minimize emissions to the maximum extent possible.
(iii) For each well designated facility that reduces methane emissions from well designated facility gas wells that unload liquids by 95.0 percent by routing emissions to a control device through closed vent system under § 60.5390c(g), you must maintain the records in paragraphs (c)(1)(iii)(A) through (E) of this section.
(A) If you comply with the emission reduction standard with a control device, the information for each control device in paragraph (c)(10) of this section.
(B) Records of the closed vent system inspection as specified paragraph (c)(7) of this section.
(C) Records of the cover inspections as specified in paragraph (c)(8) of this section.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(9) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(11) of this section.
(2) For each associated gas well, you must maintain the applicable records specified in paragraphs (c)(2)(i) or (ii) and (vi) of this section, as applicable.
(i) For each associated gas well that complies with the requirements of § 60.5391c(a)(1), (2), (3), or (4), you must keep the records specified in paragraphs (c)(2)(i)(A) and (B) of this section.
(A) Documentation of the specific method(s) in § 60.5391c(a)(1), (2), (3), or (4) that was used.
(B) For instances where you temporarily route the associated gas to a flare or control device in accordance with § 60.5391c(c), you must keep the records specified in paragraphs (c)(2)(i)(B)( 1) through ( 3) of this section.
( 1) The reason in § 60.5391c(c)(1), (2), (3), or (4) for each incident.
( 2) The date of each incident, along with the times when routing the associated gas to the flare or control device started and ended, along with the total duration of each incident.
( 3) Documentation that all CVS requirements specified in § 60.5411c(a) and (c) and all applicable flare or control device requirements specified in § 60.5412c are met during each period when the associated gas is routed to the flare or control device.
(ii) For instances where you temporarily vent the associated gas in accordance with § 60.5391c(d), you must keep the records specified in paragraphs (c)(2)(ii)(A) through (D) of this section. These records are required if you are routinely complying with § 60.5391c(a) or § 60.5391c(b) or temporarily complying with § 60.5391c(c).
(A) The reason in § 60.5391c(d)(1), (2), or (3) for each incident.
(B) The date of each incident, along with the times when venting the associated gas started and ended, along with the total duration of each incident.
(C) The methane emissions that were emitted during each incident.
(D) The cumulative duration of venting incidents and methane emissions for all incidents in each calendar year.
(iii) For each associated gas well that complies with the requirements of § 60.5391c(b) because it has demonstrated that annual methane emissions are 40 tons per year or less at the initial compliance date, maintain records of the calculation of annual methane emissions determined in accordance with § 60.5391c(e)(1).
(iv) For each associated gas well at your well that complies with the requirements of § 60.5391c(b) because it has demonstrated that it is not feasible to comply with § 60.5391c(a)(1), (2), (3), or (4) due to technical reasons, records of each annual demonstration and certification of the technical reason that it is not feasible to comply with § 60.5391c(a)(1), (2), (3), and (4) in accordance with § 60.5391c(b)(2)(i), (ii), and (iii), as well as the records required by paragraph (c)(2)(v) of this section.
(v) For each associated gas well that complies with the requirements of § 60.5391c(b) by routing your associated gas to a flare or control device that achieves a 95.0 reduction in methane emissions, the records in paragraphs (c)(2)(v)(A) through (E) of this section.
(A) Identification of each instance when associated gas was vented and not routed to a control device that reduces methane emissions by at least 95.0 percent in accordance with paragraph (c)(2)(iii) of this section.
(B) If you comply with the emission reduction standard in § 60.5391c with a control device, the information for each control device in paragraph (c)(10) of this section.
(C) Records of the closed vent system inspection as specified paragraph (c)(7) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (c)(7) of this section, you must maintain records of the information specified in § 60.5424c.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(9) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(11) of this section.
(vi) Records of each deviation, the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(3) For each centrifugal compressor designated facility, you must maintain the records specified in paragraphs (c)(3)(i) through (iii) of this section.
(i) For each centrifugal compressor designated facility, you must maintain records of deviations in cases where the centrifugal compressor was not operated in compliance with the requirements specified in § 60.5392c, including a description of each deviation, the date and time each deviation began and the duration of each deviation.
(ii) For each wet seal compressor complying with the emissions reduction standard in § 60.5392c(a)(3) and (4), you must maintain the records in paragraphs (c)(3)(ii)(A) through (E) of this section. For each wet seal compressor complying with the alternative standard in § 60.5392c(a)(3) and (5) by routing the closed vent system to a process, you must maintain the records in paragraphs (c)(3)(ii)(B) through (E) of this section.
(A) If you comply with the emission reduction standard in § 60.5392c(a)(3) and (4) with a control device, the information for each control device in paragraph (c)(10) of this section.
(B) Records of the closed vent system inspection as specified paragraph (c)(7) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (c)(7) of this section, you must maintain records of the information specified in § 60.5424c.
(C) Records of the cover inspections as specified in paragraph (c)(8) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraph (c)(8) of this section, you must maintain the information specified in § 60.5424c.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(9) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(11) of this section.
(iii) For each centrifugal compressor designated facility using dry seals or wet seals and each self-contained wet seal centrifugal compressor and complying with the standard in § 60.5392c(a)(1) and (2), you must maintain the records specified in paragraphs (c)(3)(iii)(A) through (H) of this section.
(A) Records of the cumulative number of hours of operation since initial startup, since 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), or since the previous volumetric flow rate measurement, as applicable.
(B) A description of the method used and the results of the volumetric flow rate measurement or emissions screening, as applicable.
(C) Records for all flow meters, composition analyzers and pressure gauges used to measure volumetric flow rates as specified in paragraphs (c)(3)(iii)(C)( 1) through ( 6) of this section.
( 1) Description of standard method published by a consensus-based standards organization or industry standard practice.
( 2) Records of volumetric flow rate emissions calculations conducted according to § 60.5392c(a)(2), as applicable.
( 3) Records of manufacturer operating procedures and measurement methods.
( 4) Records of manufacturer's recommended procedures or an appropriate industry consensus standard method for calibration and results of calibration, recalibration and accuracy checks.
( 5) Records which demonstrate that measurements at the remote location(s) can, when appropriate correction factors are applied, reliably and accurately represent the actual temperature or total pressure at the flow meter under all expected ambient conditions. You must include the date of the demonstration, the data from the demonstration, the mathematical correlation(s) between the remote readings and actual flow meter conditions derived from the data, and any supporting engineering calculations. If adjustments were made to the mathematical relationships, a record and description of such adjustments.
( 6) Record of each initial calibration or a recalibration which failed to meet the required accuracy specification and the date of the successful recalibration.
(D) Date when performance-based volumetric flow rate is exceeded.
(E) The date of successful repair of the compressor seal, including follow-up performance-based volumetric flow rate measurement to confirm successful repair.
(F) Identification of each compressor seal placed on delay of repair and explanation for each delay of repair.
(G) For each compressor seal or part needed for repair placed on delay of repair because of replacement seal or part unavailability, the operator must document: the date the seal or part was added to the delay of repair list, the date the replacement seal or part was ordered, the anticipated seal or part delivery date (including any estimated shipment or delivery date provided by the vendor), and the actual arrival date of the seal or part.
(H) Date of planned shutdowns that occur while there are any seals or parts that have been placed on delay of repair.
(4) For each reciprocating compressor designated facility, you must maintain the records in paragraphs (c)(4)(i) through (x) and (c)(7) through (12) of this section, as applicable. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraph (c)(7) of this section, you must provide the information specified in § 60.5424c.
(i) For each reciprocating compressor designated facility, you must maintain records of deviations in cases where the reciprocating compressor was not operated in compliance with the requirements specified in § 60.5393c, including a description of each deviation, the date and time each deviation began and the duration of each deviation in hours.
(ii) Records of the date of installation of a rod packing emissions collection system and closed vent system as specified in § 60.5393c(d), where applicable.
(iii) Records of the cumulative number of hours of operation since initial startup, since 36 months after the state plan submittal deadline (as specified in § 60.5362c(c)), or since the previous volumetric flow rate measurement, as applicable. Alternatively, a record that emissions from the rod packing are being routed to a process through a closed vent system.
(iv) A description of the method used and the results of the volumetric flow rate measurement or emissions screening, as applicable.
(v) Records for all flow meters, composition analyzers and pressure gauges used to measure volumetric flow rates as specified in paragraphs (c)(4)(v)(A) through (F) of this section.
(A) Description of standard method published by a consensus-based standards organization or industry standard practice.
(B) Records of volumetric flow rate calculations conducted according to paragraphs § 60.5393c(b) or (c), as applicable.
(C) Records of manufacturer's operating procedures and measurement methods.
(D) Records of manufacturer's recommended procedures or an appropriate industry consensus standard method for calibration and results of calibration, recalibration and accuracy checks.
(E) Records which demonstrate that measurements at the remote location(s) can, when appropriate correction factors are applied, reliably and accurately represent the actual temperature or total pressure at the flow meter under all expected ambient conditions. You must include the date of the demonstration, the data from the demonstration, the mathematical correlation(s) between the remote readings and actual flow meter conditions derived from the data, and any supporting engineering calculations. If adjustments were made to the mathematical relationships, a record and description of such adjustments.
(F) Record of each initial calibration or a recalibration which failed to meet the required accuracy specification and the date of the successful recalibration.
(vi) Date when performance-based volumetric flow rate is exceeded.
(vii) The date of successful replacement or repair of reciprocating compressor rod packing, including follow-up performance-based volumetric flow rate measurement to confirm successful repair.
(viii) Identification of each reciprocating compressor placed on delay of repair because of rod packing or part unavailability and explanation for each delay of repair.
(ix) For each reciprocating compressor that is placed on delay of repair because of replacement rod packing or part unavailability, the operator must document: the date the rod packing or part was added to the delay of repair list, the date the replacement rod packing or part was ordered, the anticipated rod packing or part delivery date (including any estimated shipment or delivery date provided by the vendor), and the actual arrival date of the rod packing or part.
(x) Date of planned shutdowns that occur while there are any reciprocating compressors that have been placed on delay of repair due to the unavailability of rod packing or parts to conduct repairs.
(5) For each process controller designated facility, you must maintain the records specified in paragraphs (c)(5)(i) through (vii) of this section.
(i) Records identifying each process controller that is driven by natural gas and that does not function as an emergency shutdown device.
(ii) For each process controller designated facility complying with § 60.5394c(a), you must maintain records of the information specified in paragraphs (c)(5)(ii)(A) and (B) of this section, as applicable.
(A) If you are complying with § 60.5394c(a) by routing process controller vapors to a process through a closed vent system, you must report the information specified in paragraphs (c)(5)(ii)(A)( 1) and ( 2) of this section.
( 1) An identification of all the natural gas-driven process controllers in the process controller designated facility for which you collect and route vapors to a process through a closed vent system.
( 2) The records specified in paragraphs (c)(7), (9), and (11) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraph (c)(7) of this section, you must provide the information specified in § 60.5424c.
(B) If you are complying with § 60.5394c(a) by using a self-contained natural gas-driven process controller, you must report the information specified in paragraphs (c)(5)(ii)(B)( 1) through ( 3) of this section.
( 1) An identification of each process controller complying with § 60.5394c(a) by using a self-contained natural gas-driven process controller;
( 2) Dates of each inspection required under § 60.5416c(b); and
( 3) Each defect or leak identified during each natural gas-driven-self-contained process controller system inspection, and date of repair or date of anticipated repair if repair is delayed.
(iii) For each process controller designated facility complying with § 60.5394c(b)(1) process controller bleed rate requirements, you must maintain records of the information specified in paragraphs (c)(5)(iii)(A) and (B) of this section.
(A) The identification of process controllers designed and operated to achieve a bleed rate less than or equal to 6 scfh and records of the manufacturer's specifications indicating that the process controller is designed with a natural gas bleed rate of less than or equal to 6 scfh.
(B) Where necessary to meet a functional need, the identification of the process controller and demonstration of why it is necessary to use a process controller with a natural gas bleed rate greater than 6 scfh.
(iv) For each intermittent vent process controller in the designated facility complying with the requirements in § 60.5394c(b)(2), you must keep records of the information specified in paragraphs (c)(5)(iv)(A) through (C) of this section.
(A) The identification of each intermittent vent process controller.
(B) Dates and results of the intermittent vent process controller monitoring required by § 60.5394c(b)(2)(ii).
(C) For each instance in which monitoring identifies emissions to the atmosphere from an intermittent vent controller during idle periods, the date of repair or replacement, or the date of anticipated repair or replacement if the repair or replacement is delayed and the date and results of the re-survey after repair or replacement.
(v) For each process controller designated facility complying with § 60.5394c(b)(3), you must maintain the records specified in paragraphs (c)(5)(v)(A) and (B) of this section.
(A) An identification of each process controller for which emissions are routed to a control device.
(B) Records specified in paragraphs (c)(7) and (9) through (12) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (c)(7) of this section, you must provide the information specified in § 60.5424c.
(vi) Records of each change in compliance method, including identification of each natural gas-driven process controller which changes its method of compliance, the new method of compliance, and the date of the change in compliance method.
(vii) Records of each deviation, the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(6) For each storage vessel designated facility, you must maintain the records identified in paragraphs (c)(6)(i) through (vii) of this section.
(i) You must maintain records of the identification and location in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983 of each storage vessel designated facility.
(ii) Records of each methane emissions determination for each storage vessel designated facility made under § 60.5386c(e) including identification of the model or calculation methodology used to calculate the methane emission rate.
(iii) For each instance where the storage vessel was not operated in compliance with the requirements specified in § 60.5396c, a description of the deviation, the date and time each deviation began, and the duration of the deviation.
(iv) If complying with the emissions reduction standard in § 60.5396c(a)(1), you must maintain the records in paragraphs (c)(6)(iv)(A) through (E) of this section.
(A) If you comply with the emission reduction standard with a control device, the information for each control device in paragraph (c)(10) of this section.
(B) Records of the closed vent system inspection as specified paragraph (c)(7) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraph (c)(7) of this section, you must provide the information specified in § 60.5424c.
(C) Records of the cover inspections as specified in paragraph (c)(8) of this section. If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraph (c)(8) of this section, you must provide the information specified in § 60.5424c.
(D) If applicable, the records of bypass monitoring as specified in paragraph (c)(9) of this section.
(E) Records of the closed vent system assessment as specified in paragraph (c)(11) of this section.
(v) For storage vessels that are skid-mounted or permanently attached to something that is mobile (such as trucks, railcars, barges, or ships), records indicating the number of consecutive days that the vessel is located at a site in the crude oil and natural gas source category. If a storage vessel is removed from a site and, within 30 days, is either returned to the site or replaced by another storage vessel at the site to serve the same or similar function, then the entire period since the original storage vessel was first located at the site, including the days when the storage vessel was removed, will be added to the count towards the number of consecutive days.
(vi) Records of the date that each storage vessel designated facility or portion of a storage vessel designated facility is removed from service and returned to service, as applicable.
(vii) Records of the date that liquids from the well following fracturing or refracturing are routed to the storage vessel designated facility; or the date that you comply with paragraph § 60.5396c(a)(2), following a monthly emissions determination which indicates that methane emissions increase to 14 tpy or greater and the increase is not associated with fracturing or refracturing of a well feeding the storage vessel designated facility, and records of the methane emissions rate and the model or calculation methodology used to calculate the methane emission rate.
(7) Records of each closed vent system inspection required under § 60.5416c(a)(1) and (2) and (b) for your well, centrifugal compressor, reciprocating compressor, process controller, pump, storage vessel, and process unit equipment designated facility as required in paragraphs (c)(7)(i) through (iv) of this section.
(i) A record of each closed vent system inspection or no identifiable emissions monitoring survey. You must include an identification number for each closed vent system (or other unique identification description selected by you), the date of the inspection, and the method used to conduct the inspection ( i.e., visual, AVO, OGI, Method 21 of appendix A-7 to this part).
(ii) For each defect or emissions detected during inspections required by § 60.5416c(a)(1) and (2), or (b) you must record the location of the defect or emissions; a description of the defect; the maximum concentration reading obtained if using Method 21 of appendix A-7 to this part; the indication of emissions detected by AVO if using AVO; the date of detection; the date of each attempt to repair the emissions or defect; the corrective action taken during each attempt to repair the defect; and the date the repair to correct the defect or emissions is completed.
(iii) If repair of the defect is delayed as described in § 60.5416c(b)(6), you must record the reason for the delay and the date you expect to complete the repair.
(iv) Parts of the closed vent system designated as unsafe to inspect as described in § 60.5416c(b)(7) or difficult to inspect as described in § 60.5416c(b)(8), the reason for the designation, and written plan for inspection of that part of the closed vent system.
(8) A record of each cover inspection required under § 60.5416c(a)(3) for your centrifugal compressor, reciprocating compressor, or storage vessel as required in paragraphs (c)(8)(i) through (iv) of this section.
(i) A record of each cover inspection. You must include an identification number for each cover (or other unique identification description selected by you), the date of the inspection, and the method used to conduct the inspection ( i.e., AVO, OGI, Method 21 of appendix A-7 to this part).
(ii) For each defect detected during the inspection you must record the location of the defect; a description of the defect; the date of detection; the maximum concentration reading obtained if using Method 21 of appendix A-7 to this part; the indication of emissions detected by AVO if using AVO; the date of each attempt to repair the defect; the corrective action taken during each attempt to repair the defect; and the date the repair to correct the defect is completed.
(iii) If repair of the defect is delayed as described in § 60.5416c(b)(5), you must record the reason for the delay and the date you expect to complete the repair.
(iv) Parts of the cover designated as unsafe to inspect as described in § 60.5416c(b)(7) or difficult to inspect as described in § 60.5416c(b)(8), the reason for the designation, and written plan for inspection of that part of the cover.
(9) For each bypass subject to the bypass requirements of § 60.5416c(a)(4), you must maintain a record of the following, as applicable: readings from the flow indicator; each inspection of the seal or closure mechanism; the date and time of each instance the key is checked out; date and time of each instance the alarm is sounded.
(10) Records for each control device used to comply with the emission reduction standard in § 60.5391c(b) for associated gas wells, § 60.5392c(a)(4) for centrifugal compressor designated facilities, § 60.5393c(d)(2) for reciprocating compressor designated facilities, § 60.5394c(b)(3) for your process controller designated facility in Alaska, § 60.5395c(b)(3) for your pump designated facility, § 60.5396c(a)(2) for your storage vessel designated facility, § 60.5390c(g) for well designated facility gas well liquids unloading, or § 60.5400c(f) or 60.5401c(e) for your process equipment designated facility, as required in paragraphs (c)(10)(i) through (viii) of this section. If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d), keep records of the information in paragraphs (c)(10)(ix) of this section, in lieu of the records required by paragraphs (c)(10)(i) through (iv) and (vi) through (viii) of this section.
(i) For a control device tested under § 60.5413c(d) which meets the criteria in § 60.5413c(d)(11) and (e), keep records of the information in paragraphs (c)(10)(i)(A) through (E) of this section, in addition to the records in paragraphs (c)(10)(ii) through (ix) of this section, as applicable.
(A) Serial number of purchased device and copy of purchase order.
(B) Location of the designated facility associated with the control device in latitude and longitude coordinates in decimal degrees to an accuracy and precision of five (5) decimals of a degree using the North American Datum of 1983.
(C) Minimum and maximum inlet gas flow rate specified by the manufacturer.
(D) Records of the maintenance and repair log as specified in § 60.5413c(e)(4), for all inspection, repair, and maintenance activities for each control device failing the visible emissions test.
(E) Records of the manufacturer's written operating instructions, procedures, and maintenance schedule to ensure good air pollution control practices for minimizing emissions.
(ii) For all control devices, keep records of the information in paragraphs (c)(10)(ii)(A) through (G) of this section, as applicable.
(A) Make, model, and date of installation of the control device, and identification of the designated facility controlled by the device.
(B) Records of deviations in accordance with § 60.5417c(g)(1) through (7), including a description of the deviation, the date and time the deviation began, the duration of the deviation, and the cause of the deviation.
(C) The monitoring plan required by § 60.5417c(c)(2).
(D) Make and model number of each continuous parameter monitoring system.
(E) Records of minimum and maximum operating parameter values, continuous parameter monitoring system data (including records that the pilot or combustion flame is present at all times), calculated averages of continuous parameter monitoring system data, and results of all compliance calculations.
(F) Records of continuous parameter monitoring system equipment performance checks, system accuracy audits, performance evaluations, or other audit procedures and results of all inspections specified in the monitoring plan in accordance with § 60.5417c(c)(2). Records of calibration gas cylinders, if applicable.
(G) Periods of monitoring system malfunctions, repairs associated with monitoring system malfunctions and required monitoring system quality assurance or quality control activities Records of repairs on the monitoring system.
(iii) For each carbon adsorption system, records of the schedule for carbon replacement as determined by the design analysis requirements of § 60.5413c(c)(2) and (3) and records of each carbon replacement as specified in § 60.5412c(c)(1) and § 60.5415c(e)(1)(viii).
(iv) For enclosed combustion devices and flares, records of visible emissions observations as specified in paragraph (c)(10)(iv)(A) or (B) of this section.
(A) Records of observations with Method 22 of appendix A-7 to this part, including observations required following return to operation from a maintenance or repair activity, which include: company, location, company representative (name of the person performing the observation), sky conditions, process unit (type of control device), clock start time, observation period duration (in minutes and seconds), accumulated emission time (in minutes and seconds), and clock end time. You may create your own form including the above information or use Figure 22-1 in Method 22 of appendix A-7 to this part.
(B) If you monitor visible emissions with a video surveillance camera, location of the camera and distance to emission source, records of the video surveillance output, and documentation that an operator looked at the feed daily, including the date and start time of observation, the length of observation, and length of time visible emissions were present.
(v) For enclosed combustion devices and flares, video of the OGI inspection conducted in accordance with § 60.5415c(e)(1)(x). Records documenting each enclosed combustion device and flare was visibly observed during each inspection conducted under § 60.5397c using AVO in accordance with § 60.5415c(e)(1)(x).
(vi) For enclosed combustion devices and flares, records of each demonstration of the NHV of the inlet gas to the enclosed combustion device or flare conducted in accordance with § 60.5417c(d)(8)(iii). For each re-evaluation of the NHV of the inlet gas, records of process changes and explanation of the conditions that led to the need to re-evaluation the NHV of the inlet gas. For each demonstration, record information on whether the enclosed combustion device or flare has the potential to receive inert gases, and if so, the highest percentage of inert gases that can be sent to the enclosed combustion device or flare and the highest percent of inert gases sent to the enclosed combustion device or flare during the NHV demonstration. Records of periodic sampling conducted under § 60.5417c(d)(8)(iii)(G).
(vii) For enclosed combustion devices and flares, if you use a backpressure regulator valve, the make and model of the valve, date of installation, and record of inlet flow rating. Maintain records of the engineering evaluation and manufacturer specifications that identify the pressure set point corresponding to the minimum inlet gas flow rate, the annual confirmation that the backpressure regulator valve set point is correct and consistent with the engineering evaluation and manufacturer specifications, and the annual confirmation that the backpressure regulator valve fully closes when not in open position.
(viii) For enclosed combustion devices and flares, records of each demonstration required under § 60.5417c(d)(8)(iv).
(ix) If you use an enclosed combustion device or flare using an alternative test method approved under § 60.5412c(d), keep records of the information in paragraphs (c)(10)(ix)(A) through (H) of this section, in lieu of the records required by paragraphs (c)(10)(i) through (iv) and (vi) through (viii) of this section.
(A) An identification of the alternative test method used.
(B) Data recorded at the intervals required by the alternative test method.
(C) Monitoring plan required by § 60.5417c(i)(2).
(D) Quality assurance and quality control activities conducted in accordance with the alternative test method.
(E) If required by § 60.5412c(d)(4) to conduct visible emissions observations, records required by paragraph (c)(10)(iv) of this section.
(F) If required by § 60.5412c(d)(5) to conduct pilot or combustion flame monitoring, record indicating the presence of a pilot or combustion flame and periods when the pilot or combustion flame is absent.
(G) For each instance where there is a deviation of the control device in accordance with § 60.5417c(i)(6)(i) through (v), the date and time the deviation began, the duration of the deviation in hours, and cause of the deviation.
(H) Any additional information required to be recorded as specified by the Administrator as part of the alternative test method approval under § 60.5412c(d).
(11) For each closed vent system routing to a control device or process, the records of the assessment conducted according to § 60.5411c(c):
(i) A copy of the assessment conducted according to § 60.5411c(c)(1); and
(ii) A copy of the certification according to § 60.5411c(c)(1)(i) and (ii).
(12) A copy of each performance test submitted under paragraphs (b)(11) or (12) of this section.
(13) For the fugitive emissions components designated facility, maintain the records identified in paragraphs (c)(13)(i) through (vii) of this section.
(i) The date of the startup of production or the date of the first day of production after modification for the fugitive emissions components designated facility at a well site and the date of startup or the date of modification for the fugitive emissions components designated facility at a compressor station.
(ii) For the fugitive emissions components designated facility at a well site, you must maintain records specifying what type of well site it is ( i.e., single wellhead only well site, small wellsite, multi-wellhead only well site, or a well site with major production and processing equipment.)
(iii) For the fugitive emissions components designated facility at a well site where you complete the removal of all major production and processing equipment such that the well site contains only one or more wellheads, record the date the well site completes the removal of all major production and processing equipment from the well site, and, if the well site is still producing, record the well ID or separate tank battery ID receiving the production from the well site. If major production and processing equipment is subsequently added back to the well site, record the date that the first piece of major production and processing equipment is added back to the well site.
(iv) The fugitive emissions monitoring plan as required in § 60.5397c(b), (c), and (d).
(v) The records of each monitoring survey as specified in paragraphs (c)(13)(v)(A) through (I) of this section.
(A) Date of the survey.
(B) Beginning and end time of the survey.
(C) Name of operator(s), training, and experience of the operator(s) performing the survey.
(D) Monitoring instrument or method used.
(E) Fugitive emissions component identification when Method 21 of appendix A-7 to this part is used to perform the monitoring survey.
(F) 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.
(G) Any deviations from the monitoring plan or a statement that there were no deviations from the monitoring plan.
(H) Records of calibrations for the instrument used during the monitoring survey.
(I) Documentation of each fugitive emission detected during the monitoring survey, including the information specified in paragraphs (c)(13)(v)(I)( 1) through ( 9) of this section.
( 1) Location of each fugitive emission identified.
( 2) Type of fugitive emissions component, including designation as difficult-to-monitor or unsafe-to-monitor, if applicable.
( 3) If Method 21 of appendix A-7 to this part is used for detection, record the component ID and instrument reading.
( 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.
( 5) The date of first attempt at repair of the fugitive emissions component(s).
( 6) The date of successful repair of the fugitive emissions component, including the resurvey to verify repair and instrument used for the resurvey.
( 7) Identification of each fugitive emission component placed on delay of repair and explanation for each delay of repair.
( 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.
( 9) Date of planned shutdowns that occur while there are any components that have been placed on delay of repair.
(vi) For well closure activities, you must maintain the information specified in paragraphs (c)(13)(vi)(A) through (G) of this section.
(A) The well closure plan developed in accordance with § 60.5397c(l) and the date the plan was submitted.
(B) The notification of the intent to close the well site and the date the notification was submitted.
(C) The date of the cessation of production from all wells at the well site.
(D) The date you began well closure activities at the well site.
(E) Each status report for the well closure activities reported in paragraph (b)(8)(iv)(A) of this section.
(F) Each OGI survey reported in paragraph (b)(8)(iv)(B) of this section including the date, the monitoring instrument used, and the results of the survey or resurvey.
(G) The final OGI survey video demonstrating the closure of all wells at the site. The video must include the date that the video was taken and must identify the well site location by latitude and longitude.
(vii) If you comply with an alternative GHG standard under § 60.5398c, in lieu of the information specified in paragraphs (c)(13)(iv) and (v) of this section, you must maintain the records specified in § 60.5424c.
(14) For each pump designated facility, you must maintain the records identified in paragraphs (c)(14)(i) through (ix) of this section, as applicable.
(i) Identification of each pump that is driven by natural gas and that is in operation 90 days or more per calendar year.
(ii) If you are complying with § 60.5395c(a) or (b)(1) by routing pump vapors to a process through a closed vent system, identification of all the natural gas-driven pumps in the pump designated facility for which you collect and route vapors to a process through a closed vent system and the records specified in paragraphs (c)(7), (9), and (11) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398c, in lieu of the information specified in paragraph (c)(7) of this section, you must provide the information specified in § 60.5424c.
(iii) If you are complying with § 60.5395c(b)(1) by routing pump vapors to control device achieving a 95.0 percent reduction in methane emissions, you must keep the records specified in paragraphs (c)(7) and (c)(9) through (c)(12) of this section. If you comply with an alternative GHG and VOC standard under § 60.5398c, in lieu of the information specified in paragraph (c)(7) of this section, you must provide the information specified in § 60.5424c.
(iv) If you are complying with § 60.5395c(b)(3) by routing pump vapors to a control device achieving less than a 95.0 percent reduction in methane emissions, you must maintain records of the certification that there is a control device on site but it does not achieve a 95.0 percent emissions reduction and a record of the design evaluation or manufacturer's specifications which indicate the percentage reduction the control device is designed to achieve.
(v) If you have less than three natural gas-driven diaphragm pumps in the pump designated facility, and you do not have a vapor recovery unit or control device installed on site by the compliance date, you must retain a record of your certification required under § 60.5395c(b)(4), certifying that there is no vapor recovery unit or control device on site. If you subsequently install a control device or vapor recovery unit, you must maintain the records required under paragraphs (c)(14)(ii) and (iii) or (iv) of this section, as applicable.
(vi) If you determine, through an engineering assessment, that it is technically infeasible to route the pump designated facility emissions to a process or control device, you must retain records of your demonstration and certification that it is technically infeasible as required under § 60.5395c(b)(7).
(vii) If the pump is routed to a process or control device that is subsequently removed from the location or is no longer available such that there is no option to route to a process or control device, you are required to retain records of this change and the records required under paragraph (c)(14)(vi) of this section.
(viii) Records of each change in compliance method, including identification of each natural gas-driven pump which changes its method of compliance, the new method of compliance, and the date of the change in compliance method.
(ix) Records of each deviation, the date and time the deviation began, the duration of the deviation, and a description of the deviation.
(d) Electronic reporting. If you are required to submit notifications or reports following the procedure specified in this paragraph (d), 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 paragraphs (d)(1) and (2) of this section. 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 (d).
* * * * *63. Amend § 60.5421c by revising the introductory text and paragraph (b) introductory text to read as follows:
What are my additional recordkeeping requirements for process unit equipment designated facilities?You must maintain a record of each equipment leak monitoring inspection and each leak identified under § 60.5400c and § 60.5401c as specified in paragraphs (b)(1) through (17) of this section. The record must be maintained either onsite or at the nearest local field office for at least 5 years. Any records required to be maintained 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.
* * * * *(b) You must maintain the monitoring inspection records specified in paragraphs (b)(1) through (17) of this section.
* * * * *64. Amend § 60.5424c by revising paragraph (e)(6) to read as follows:
What are my additional recordkeeping and reporting requirements if I comply with the alternative GHG standards for fugitive emissions components designated facilities and covers and closed vent systems?* * * * *(e) * * *
(6) Each rolling 12-month average operational downtime for the system, calculated in accordance with § 60.5398c(c)(1)(iv)(D).
* * * * *65. Amend § 60.5430c by revising the definitions of Initial calibration value, No identifiable emissions,Repaired, and Storage vessel to read as follows:
What definitions apply to this subpart?* * * * *Initial calibration value, as used in the standards and requirements of this subpart relative to the process unit equipment designated facility at onshore natural gas processing plants, means the concentration measured during the initial calibration at the beginning of each day required in § 60.5406c, or the most recent calibration if the instrument is recalibrated during the day ( i.e., the calibration is adjusted) after a calibration drift assessment.
* * * * *No identifiable emissions means, for the purposes of covers, closed vent systems, and self-contained natural gas-driven process controllers and as determined according to the provisions of § 60.5416c, that no emissions are detected by AVO means when inspections are conducted by AVO; no emissions are imaged with an OGI camera when inspections are conducted with OGI; and equipment is operating with an instrument reading of less than 500 ppmv above background, as determined by Method 21 of appendix A-7 to this part when inspections are conducted with Method 21.
* * * * *Repaired means the following:
(1) For the purposes of fugitive emissions components designated facilities, that fugitive emissions components are adjusted, replaced, or otherwise altered, in order to eliminate fugitive emissions as defined in § 60.5397c and resurveyed as specified in § 60.5397c(h)(4) and it is verified that emissions from the fugitive emissions components are below the applicable fugitive emissions definition.
(2) For the purposes of process unit equipment designated facilities, that equipment is adjusted, or otherwise altered, in order to eliminate a leak as defined in §§ 60.5400c and 60.5401c and is re-monitored as specified in § 60.5400c(b) introductory text or § 60.5406c, respectively, to verify that emissions from the equipment are below the applicable leak definition. Pumps in light liquid service subject to § 60.5400c(c)(2) or § 60.5401c(b)(1)(ii) are not subject to re-monitoring.
* * * * *Storage vessel means a tank or other vessel that contains an accumulation of crude oil, condensate, intermediate hydrocarbon liquids, or produced water, and that is constructed primarily of nonearthen materials (such as wood, concrete, steel, fiberglass, or plastic) which provide structural support. A well completion vessel that receives recovered liquids from a well after startup of production following flowback for a period which exceeds 60 days is considered a storage vessel under this subpart. A tank or other vessel shall not be considered a storage vessel if it has been removed from service in accordance with the requirements of § 60.5396c(c)(1) until such time as such tank or other vessel has been returned to service. For the purposes of this subpart, the following are not considered storage vessels:
(1) Vessels that are skid-mounted or permanently attached to something that is mobile (such as trucks, railcars, barges or ships), and are intended to be located at a site for less than 180 consecutive days. If you do not keep or are not able to produce records, as required by § 60.5420c(c)(6)(v), showing that the vessel has been located at a site for less than 180 consecutive days, the vessel described herein is considered to be a storage vessel from the date the original vessel was first located at the site. This exclusion does not apply to a well completion vessel as described above.
(2) Process vessels such as surge control vessels, bottoms receivers or knockout vessels.
(3) Pressure vessels designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere.
* * * * *66. Revise table 1 to subpart OOOOc of part 60 to read as follows:
Table 1 to Subpart OOOO c of Part 60—Designated Facility Presumptive Standards and Regulated Entity Compliance Dates
Designated facility Model rule presumptive standards section Regulated entity compliance dates Wells a. Gas wells liquids unloading events—§ 60.5390c b. Associated gas wells—§ 60.5391c 36 months after the state plan submittal deadline specified in § 60.5362c(c). Centrifugal Compressors § 60.5392c Reciprocating Compressors § 60.5393c Process Controllers § 60.5394c Pumps § 60.5395c Storage Vessels § 60.5396c Fugitive Emissions Components a. Primary standards—§ 60.5397c b. Alternative standards for fugitive emissions components and covers and closed vent systems—§ 60.5398c Super Emitter Events § 60.5388c Process Unit Equipment a. Onshore natural gas processing plants—§ 60.5400c b. Process unit equipment alternative standards—§ 60.5401c c. Process unit equipment requirement exceptions—§ 60.5402c 67. Amend table 4 to subpart OOOOc of part 60 by revising the entry for “§ 60.8” to read as follows:
Table 4 to Subpart OOOO c of Part 60—Applicability of General Provisions to Subpart OOOO c
General provisions citation Subject of citation Applies to subpart? Explanation * * * * * * * § 60.8 Performance tests Yes Except that the format and submittal of performance test reports is described in § 60.5420c(b) and (d). Performance testing is required for control devices used on wells, storage vessels, centrifugal compressors, reciprocating compressors, process controllers, and pumps, as applicable, except that performance testing is not required for a control device used solely on pump(s). * * * * * * *
Document Information
- Effective Date:
- 8/1/2024
- Published:
- 08/01/2024
- Department:
- Environmental Protection Agency
- Entry Type:
- Rule
- Action:
- Interim final rule; correction; request for comments.
- Document Number:
- 2024-13206
- Dates:
- This rule is effective on August 1, 2024. Comments on this interim final rule must be received on or before September 3, 2024.
- Pages:
- 62872-62949 (78 pages)
- Docket Numbers:
- EPA-HQ-OAR-2021-0317, FRL-11890-01-OAR
- RINs:
- 2060-AW18: Standards of Performance for New, Reconstructed, and Modified Sources and Emissions Guidelines for Existing Sources: Oil and Natural Gas Sector Climate Review final rule-Technical Correction
- RIN Links:
- https://www.federalregister.gov/regulations/2060-AW18/standards-of-performance-for-new-reconstructed-and-modified-sources-and-emissions-guidelines-for-exi
- Topics:
- Administrative practice and procedure, Air pollution control, Environmental protection, Intergovernmental relations, Reporting and recordkeeping requirements
- PDF File:
- 2024-13206.pdf
- Supporting Documents:
- » Daryl Junes Joe - Abbreviated Statement on Public Hearing
- » Memorandum to Docket EPA-HQ-OAR-2021-0317 from Gerri G. Garwood, P.E., EPA. Subject: References Listed in the Technical Support Document for Appendix K. November 8, 2021
- » Colorado Oil & Gas Conservation Commission. Regulatory Process for Permitting and Tracking an Oil or Gas Well
- » U.S. EPA. Oil and Natural Gas Sector: Emission Standards for New, Reconstructed, and Modified Sources and Emissions Guidelines for Existing Sources: Background Technical Support Document (TSD) for the Proposed New Source Performance Standards (NSPS) and Emissions Guidelines (EG). October 2021. Supporting spreadsheets for Chapter 5 and Chapters 7 through 13 attached
- » Integrated Science Assessment for Ozone and Related Photochemical Oxidants (Final Report). U.S. EPA. (2013). EPA-600-R-10-076F. National Center for Environmental Assessment—RTP Division
- » Federal Energy Regulatory Commission. Oil. Website: https://www.ferc.gov/industries-data/oil
- » National Academies of Sciences, Engineering, and Medicine. Attribution of Extreme Weather Events in the Context of Climate Change. Washington, DC: The National Academies Press. (2016)
- » Interagency Review: EO 12866 Emails. Correspondence from OMB indicating conclusion of their review/EPA acknowledgement. November 1, 2021
- » Interagency Review: EO 12866 e-mail transmittal of clean and red-line strike-out versions of changes made to review documents. October 27, 2021. Transmitted EO 12866 review documents attached
- » E-mail correspondence related to U.S. EPA Meeting with ESG Signals, June 28, 2021