(a) For a WEC applicable facility meeting all criteria in § 99.30(a) through (e), you may elect to report information regarding an exemption for unreasonable delay in permitting of gathering or transmission infrastructure for a given reporting year. The unreasonable delay exemption information to be reported is described in paragraph (b) of this section. The unreasonable delay exemption information shall be submitted as described in § 99.7.
(b) For each unreasonable delay exemption, the WEC obligated party must report the information specified in paragraphs (b)(1) through (13) of this section.
(1) The company name and name of the facility that submitted the environmental permit application to construct and/or operate gathering or transmission infrastructure.
(2) For reporting year 2025 and later, for a WEC applicable facility in the onshore petroleum and natural gas production industry segment, as that industry segment term is defined in § 98.230 of this chapter, the well-pad ID, as reported pursuant to § 98.236(aa)(1)(iii)(B) of this chapter, of each well-pad impacted by the unreasonable delay in environmental permitting of gathering or transmission infrastructure.
(3) The date the environmental permit application request experiencing an unreasonable delay to build gathering or transmission infrastructure was submitted to the permitting authority and the date the permitting authority determined the application to be technically complete.
(4) A certification that the WEC obligated party seeking to exempt a portion of its facility applicable emissions from a WEC applicable facility has not contributed to the unreasonable delay, has been responsive to the relevant permitting authority regarding the environmental permit application and is not a plaintiff in litigation related to the environmental permit application. For purposes of this paragraph, responsive shall be interpreted to mean that the entity has responded to all requests from the permitting authority within the time frame requested or agreed to by the relevant authority or within thirty (30) days if no timeframe is specified.
(5) A listing of methane emissions mitigation activities that are impacted by the unreasonable permitting delay.
(6) The estimated date to commence operation of the gathering or transmission infrastructure if the application had been approved within thirty-six (36) months.
(7) If the application has been approved and operations commenced during the reporting year, the first date that offtake to the gathering or transmission infrastructure from the implementation of methane emissions mitigation occurred.
(8) The beginning and ending date for which the eligible delay limited the offtake of increased volume associated with methane emissions mitigation activities for the reporting year as determined according to § 99.32(a).
(9) The increased volumes of gas resulting from methane emissions mitigation implementation as determined according to § 99.32(b), in thousand standard cubic feet. For reporting year 2024, report these values for the WEC applicable facility. For reporting year 2025 and later, if the WEC applicable facility is in the onshore petroleum and natural gas production industry segment, report these values for each well-pad site reported in paragraph (b)(2) of this section. Report the increased volumes associated with each of the following:
(i) Onsite fuel source.
(ii) Another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source.
(iii) Reinjection into a well.
(iv) Flaring.
(10) The quantity of methane emissions to be exempted due to the unreasonable delay for the reporting year calculated as specified in § 99.32.
(i) For a WEC applicable facility in the offshore petroleum and natural gas production industry segment, report the following for the WEC applicable facility:
(A) The result of equation C-1 of § 99.32(c)(1), in metric tons CH4.
(B) The quantity of methane emissions from another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, (EUse,CH4), in metric tons CH4.
(C) The quantity of methane emissions from reinjection of recovered gas (EReinject,CH4), in metric tons CH4.
(D) The quantity of methane emissions from flaring (EFlare,CH4), in metric tons CH4.
(E) The total quantity of natural gas that was flared at the WEC applicable facility in the reporting year, in thousand scf.
(ii) For a WEC applicable facility in the onshore petroleum and natural gas production industry segment, for reporting year 2024 report the following for the WEC applicable facility:
(A) The result of equation C-2 of § 99.32(c)(2), in metric tons CH4.
(B) The quantity of methane emissions from use as an onsite fuel source of increased volume of natural gas resulting from methane emissions mitigation implementation (EFuel,CH4), as calculated in equation C-5 to § 99.32(c)(5), in metric tons CH4.
(C) The quantity of methane emissions from another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, (EUse,CH4), as calculated in equation C-6 to § 99.32(c)(6), in metric tons CH4.
(D) The quantity of methane emissions from reinjection of increased volume of natural gas resulting from methane emissions mitigation implementation (EReinject,CH4), as calculated in equation C-7 to § 99.32(c)(7), in metric tons CH4.
(E) The quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation (EFlare,CH4), as calculated in equation C-8B to § 99.32(c)(8), in metric tons CH4.
(iii) For a WEC applicable facility in the onshore petroleum and natural gas production industry segment, for reporting year 2025 and later, report the following for each well-pad site reported in paragraph (b)(2) of this section:
(A) The result of equation C-4 of § 99.32(c)(4), in metric tons CH4.
(B) The quantity of methane emissions from use as an onsite fuel source of increased volume of natural gas resulting from methane emissions mitigation implementation (EFuel,CH4), as calculated in equation C-5 to § 99.32(c)(5), in metric tons CH4.
(C) The quantity of methane emissions from another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, (EUse,CH4), as calculated in equation C-6 to § 99.32(c)(6), in metric tons CH4.
(D) The quantity of methane emissions from reinjection of increased volume of natural gas resulting from methane emissions mitigation implementation (EReinject,CH4), as calculated in equation C-7 to § 99.32(c)(7), in metric tons CH4.
(E) The quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation (EFlare,CH4), as calculated in equation C-8B to § 99.32(c)(8), in metric tons CH4.
(iv) For a WEC applicable facility in the onshore petroleum and natural gas production industry segment that reported emissions from use as an onsite fuel source of increased volume of natural gas resulting from methane emissions mitigation implementation (EFuel,CH4), report the information specified in paragraphs (b)(10)(iv)(A) and (B) of this section, as applicable. For reporting year 2024, report each value for the WEC applicable facility. For reporting year 2025 and later, report the value for each well-pad site.
(A) The quantity of methane emissions from combustion of increased volume of natural gas resulting from methane emissions mitigation implementation in stationary or portable fuel combustion equipment as calculated using the methods in § 98.233(z) of this chapter (ECombEq,CH4), in metric tons CH4.
(B) The total volume of natural gas combusted in reciprocating internal combustion engines with crankcase vents during the reporting year (VRICE), in thousand scf.
(v) For a WEC applicable facility in the onshore petroleum and natural gas production industry segment that reported emissions from reinjection into a well (EReinject,CH4), report the information specified in paragraphs (b)(10)(v)(A) and (B) of this section, as applicable. For reporting year 2024, report each value for the WEC applicable facility. For reporting year 2025 and later, report the value for each well-pad site.
(A) A list including each centrifugal compressor unique name or ID as submitted in the part 98 report for the WEC applicable facility that was used in the reinjection into wells of natural gas resulting from methane emissions mitigation implementation (i.e., that was included in CountCent,Reinject of equation C-7 of this part). For reporting year 2024, use the values reported to § 98.236(o)(1)(i) of this chapter. For reporting year 2025 and later, use the values reported to § 98.236(o)(1)(ii) of this chapter.
(B) A list of each reciprocating compressor unique name or ID as submitted to in the part 98 report for the WEC applicable facility that was used in the reinjection into wells of natural gas resulting from methane emissions mitigation implementation (i.e., that was included in CountRecip,Reinject of equation C-7 of this part). For reporting year 2024, use the values reported to § 98.236(p)(1)(i) of this chapter. For reporting year 2025 and later, use the values reported to § 98.236(p)(1)(ii) of this chapter.
(vi) For a WEC applicable facility in the onshore petroleum and natural gas production industry segment that reported emissions from flaring (EFlare,CH4), report the information specified in paragraphs (b)(10)(vi)(A) and (B) of this section for all reporting years. For reporting year 2025 and later, report the information specified in paragraph (b)(10)(vi)(C) of this section. For reporting year 2024, report the information specified in paragraph (b)(10)(vi)(A) for the WEC applicable facility. For reporting year 2025 and later, report the information specified in paragraph (b)(10)(vi)(A) for each well-pad site.
(A) The unique name or ID as reported pursuant to § 98.236(n)(1) of this chapter for each flare stack that flared gas resulting from methane emissions mitigation implementation.
(B) For each flare stack reported to paragraph (b)(10)(vi)(A) of this section, report the volume of natural gas resulting from methane emissions mitigation implementation that was flared at that flare as determined according to § 99.32(b)(4), in thousand scf.
(C) For each flare stack reported to paragraph (b)(10)(vi)(A) of this section, indicate if flow for each stream to the flare was measured or determined in accordance with § 98.233(n)(3)(ii) of this chapter and that stream or combination of streams contained only flow resulting from the environmental permit delay. If so, report the unique ID as reported pursuant to § 98.236(n)(3) of this chapter for each stream that contained only flow resulting from the environmental permit delay.
(vii) For a WEC applicable facility in the onshore petroleum and natural gas production industry segment that reported emissions from another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, (EUse,CH4) and/or emissions from reinjection into a well (EReinject,CH4) and quantified the equipment leaks associated with either/both use(s), report the information specified in paragraphs (b)(10)(vii)(A) through (F) of this section, as applicable. For reporting year 2024, report this information for the WEC applicable facility. For reporting year 2025 and later, report this information for each well-pad site. Report separately the information specified in paragraphs (b)(10)(vii)(A) through (F) of this section, as applicable, related to another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, and related to reinjection into a well.
(A) Indicate the method used to calculate equipment leak emissions (i.e., § 99.32(c)(9)(i), (ii), or (iii)).
(B) If the method in § 99.32(c)(9)(i) is used to calculate equipment leak emissions, you must report the following information for each leak: the leak detection survey method used, component type as reported in § 98.236(q) of this chapter, the volumetric flow rate of the natural gas leak in standard cubic feet per hour and the duration of the measured leak as determined in accordance with § 99.32(c)(9)(i), in hours. The measured leak rate, the component type and duration of measured leaks must only include those components associated with another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, or associated with reinjection into a well.
(C) If the method in § 99.32(c)(9)(ii) is used to calculate equipment leak emissions, you must report the following information for each component identified as leaking: the leak detection survey method used, the component type as specified in § 98.233(q)(2)(iii) of this chapter and the time the surveyed component is assumed to be leaking and operational, in hours. The component type and time the surveyed components are assumed to be leaking and operational must only include those components associated with another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, or associated with reinjection into a well.
(D) If the method in § 99.32(c)(9)(iii) is used to calculate equipment leak emissions, you must report the counts of each component type listed in § 98.233(r)(2) of this chapter that are associated with a useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, or associated with reinjection into a well.
(E) The mole fraction of CH4 in produced gas for the sub-basin in which the useful purpose or reinjection occurred, as reported pursuant to § 98.236(aa)(1)(ii)(I) of this chapter, unitless. For RY2024, if multiple sub-basins were impacted by the unreasonable delay, report the value of the flow-weighted average mole fraction for the sub-basins in which the useful purpose or reinjection occurred.
(F) The equipment leak emissions qualifying for exemption from another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, or reinjection into a well as calculated in accordance with paragraphs § 99.32(c)(9)(i), (ii), or (iii), metric tons CH4.
(11) A certification of the facility's compliance with all applicable local, State, and Federal regulations regarding emissions from the activities listed in § 99.30(d) that occurred as a result of a delay in environmental permitting of gathering or transmission infrastructure.
(12) For each environmental permit relevant to the exemption, the name/type of permit, permitting agency, contact information at the permitting agency, and a link to information on the permit (e.g., available through the permitting agency), if available.
(13) Upon request, any other documentation deemed necessary by the Administrator to verify eligibility under this section.
(a) Determine the time period, in days, associated with the emissions that occurred as a result of the eligible delay within the reporting year as specified in paragraphs (a)(1) and (2) of this section.
(1) The start date of the emissions caused by the delay in the reporting year is the latter of January 1 of the reporting year, or the date on which emissions would have been avoided through commencement of the operation of the gathering or transmission infrastructure if the environmental permit application to construct and/or operate the gathering or transmission infrastructure had been approved within 36 months as specified in § 99.31(b)(6).
(2) The end time of the emissions caused by the delay in the reporting year is the earlier of December 31 of the reporting year or the date the emissions caused by the unreasonable delay ended because the infrastructure commenced operation.
(b) Determine by engineering estimates based upon best available information the increased volume of gas, in thousand standard cubic feet, resulting from methane emissions mitigation implementation during the time period determined in paragraph (a) of this section associated with each of the activities listed in paragraphs (b)(1) through (4) of this section. If the WEC applicable facility is in the offshore petroleum and natural gas production industry segment, determine these values for the WEC applicable facility in every reporting year. If the WEC applicable facility is in the onshore petroleum and natural gas production industry segment, for reporting year 2024 determine these values for the WEC applicable facility, and for reporting year 2025 and later determine these values for each well-pad site impacted by the unreasonable delay.
(1) Onsite fuel source.
(2) Another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source.
(3) Reinjection into a well.
(4) Flaring. Determine this value in accordance with this paragraph (4)(i), (ii), or (iii), as applicable. For the onshore petroleum and natural gas production industry segment flaring volumes must be determined for each flare that received an increased volume of gas resulting from the environmental permit delay and then totaled for the WEC applicable facility or well-pad site, as applicable.
(i) If the WEC applicable facility is in the offshore petroleum and natural gas production industry segment determine by engineering estimate based upon best available information.
(ii) If the WEC applicable facility is in the onshore petroleum and natural gas production industry segment for reporting year 2024, determine by engineering estimate based upon best available information the portion of the flow reported pursuant to § 98.236(n)(4) of this chapter attributable to the environmental permit delay for each flare that received an increased volume of gas. If a continuous emissions monitoring system (CEMS) was used to measure emissions from the flare as reported pursuant to § 98.236(n)(12) of this chapter, do not determine a volume of gas for that flare.
(iii) If the WEC applicable facility is in the onshore petroleum and natural gas production industry segment for reporting year 2025 and later, for each flare that received an increased volume of gas attributable to the environmental permit delay, if flow for each stream to the flare is measured or determined in accordance with § 98.233(n)(3)(ii) of this chapter and that stream or combination of streams contain only flow resulting from the environmental permit delay, use the flow for those streams as reported to § 98.236(n)(11) of this chapter. If flow is measured at the inlet to the flare in accordance with § 98.233(n)(3)(i) of this chapter or the stream flow measured or determined in accordance with § 98.233(n)(3)(ii) of this chapter includes flow unrelated to the environmental permit delay, use an engineering estimate based upon best available information of the portion of flow resulting from the environmental permit delay.
(c) For each well-pad site or offshore platform at a WEC applicable facility impacted by an unreasonable delay in environmental permitting of gathering or transmission infrastructure, you must calculate the emissions that occurred at the well-pad site or offshore platform that were caused by the unreasonable delay according to paragraphs (c)(1) through (9) of this section, as applicable.
(1) For a WEC applicable facility in the offshore petroleum and natural gas production industry segment, as that industry segment term is defined in § 98.230 of this chapter, equation C-1 of this section must be used to calculate the WEC applicable facility unreasonable delay emissions.
Where:
EDelay,CH4 = The quantity of methane emissions attributable to an unreasonable delay in environmental permitting of gathering or transmission infrastructure during the reporting year at a WEC applicable facility meeting the applicability provisions of § 99.30, mt CH4.
EUse,CH4 = The WEC applicable facility quantity of methane emissions from another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, mt CH4. For reporting year 2024, use best available data to determine the portion of fugitive emissions reported pursuant to § 98.236(s)(2) of this chapter for the reporting year that were associated with another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source. For reporting year 2025 and later, use the applicable portion of the value reported to § 98.236(s)(3)(ii) of this chapter for the reporting year.
EReinject,CH4 = The WEC applicable facility quantity of methane emissions from reinjection of recovered gas, mt CH4. For reporting year 2024, use best available data to determine the portion fugitive emissions reported pursuant to § 98.236(s)(2) of this chapter for the reporting year that were associated with reinjection of recovered gas. For reporting year 2025 and later, use the applicable portion of the value reported to § 98.236(s)(3)(ii) of this chapter for the reporting year.
Td = The time period associated with the eligible delay within the reporting year, as determined pursuant to § 99.32(a), in days.
T = The number of days in the reporting year. Use 365, or for leap years, 366.
EFlare,CH4 = The WEC applicable facility quantity of methane emissions from flaring, mt CH4. For reporting year 2024, use the value reported pursuant to § 98.236(s)(2) of this chapter for the reporting year. For reporting year 2025 and later, use the value reported to § 98.236(s)(3)(ii) of this chapter for the reporting year.
VMM,Flare = The volume of natural gas resulting from methane emissions mitigation implementation that was flared as determined pursuant to § 99.32(b)(4)(i), in thousand scf.
VWAF,Flare = The total quantity of natural gas that was flared at the WEC applicable facility in the reporting year, in thousand scf.
(2) For reporting year 2024, for a WEC applicable facility in the onshore petroleum and natural gas production industry segment, as that industry segment term is defined in § 98.230 of this chapter, equation C-2 of this section must be used to calculate the WEC applicable facility unreasonable delay emissions.
Where:
EDelay,CH4 = The quantity of methane emissions attributable to an unreasonable delay in environmental permitting of gathering or transmission infrastructure during the reporting year at a WEC applicable facility meeting the applicability provisions of § 99.30, mt CH4.
EFuel,CH4 = The WEC applicable facility quantity of methane emissions from combustion of the increased volume of natural gas resulting from methane emissions mitigation implementation as calculated in accordance with paragraph (c)(5) of this section.
EUse,CH4 = The WEC applicable facility quantity of methane emissions from the increased volume of natural gas resulting from methane emissions mitigation implementation used for another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, as calculated in accordance with paragraph (c)(6) of this section.
EReinject,CH4 = The WEC applicable facility quantity of methane emissions from reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation as calculated in accordance with paragraph (c)(7) of this section.
EFlare,CH4 = The WEC applicable facility quantity of methane emissions from flaring of the increased volume of natural gas resulting from methane emissions mitigation implementation as calculated in accordance with paragraph (c)(8) of this section, mt CH4.
(3) For reporting year 2025 and later, for a WEC applicable facility in the onshore petroleum and natural gas production industry segment, as that industry segment term is defined in § 98.230 of this chapter, equation C-3 of this section must be used to calculate the WEC applicable facility unreasonable delay emissions.
Where:
EDelay,CH4 = The quantity of methane emissions at the WEC applicable facility attributable to unreasonable delay during the reporting year meeting the applicability provisions of § 99.30, mt CH4.
EWP-Delay,CH4 = The quantity of methane emissions attributable to a well-pad site “i” that met the applicability provisions of § 99.30 during the reporting year calculated using equation C-4 of this section.
N = Total number of well-pad sites that met the applicability provisions of § 99.30 during the reporting year at a WEC applicable facility.
(4) For reporting year 2025, for a WEC applicable facility in the onshore petroleum and natural gas production industry segment, as that industry segment term is defined in § 98.230 of this chapter, equation C-4 of this section must be used to calculate the unreasonable delay emissions for each affected well-pad site.
Where:
EWP-Delay,CH4 = The annual quantity of methane emissions attributable to a well-pad site impacted by an unreasonable delay in environmental permitting of gathering or transmission infrastructure during the reporting year at a WEC applicable facility meeting the applicability provisions of § 99.30, mt CH4.
EFuel,CH4 = The well-pad site quantity of methane emissions from use as an onsite fuel source of the increased volume of natural gas resulting from methane emissions mitigation implementation as calculated in accordance with paragraph (c)(5) of this section.
EUse,CH4 = The well-pad site quantity of methane emissions from the increased volume of natural gas resulting from methane emissions mitigation implementation used for another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, as calculated in accordance with paragraph (c)(6) of this section.
EReinject,CH4 = The well-pad site quantity of methane emissions from reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation as calculated in accordance with paragraph (c)(7) of this section.
EFlare,CH4 = The well-pad site quantity of methane emissions from flaring of the increased volume of natural gas resulting from methane emissions mitigation implementation as calculated in accordance with paragraph (c)(8) of this section, mt CH4.
(5) If a portion, or all, of the increased volume of natural gas resulting from methane emissions mitigation was used as an onsite fuel source, equation C-5 of this section must be used to calculate the quantity of methane emissions from use as an onsite fuel source of increased volume of natural gas resulting from methane emissions mitigation implementation.
Where:
EFuel,CH4 = The quantity of methane emissions from use as an onsite fuel source of the increased volume of natural gas resulting from methane emissions mitigation implementation, mt CH4.
ECombEq,CH4 = The quantity of methane emissions from use as an onsite fuel source of the increased volume of natural gas resulting from methane emissions mitigation implementation in stationary or portable fuel combustion equipment, mt CH4. Use the methods in § 98.233(z) of this chapter to calculate the methane emissions from the use as an onsite fuel source in stationary or portable equipment of natural gas resulting from methane emissions mitigation implementation.
ECCV,CH4 = The WEC applicable facility sum quantity of methane emissions from crankcase venting, mt CH4. For reporting year 2024, use a value of 0. For reporting year 2025 and later, use the sum total of the values reported to § 98.236(ee)(2)(ii) and (ee)(3)(iv) of this chapter for the reporting year.
VCombusted = The volume of natural gas resulting from methane emissions mitigation implementation that was used as an onsite fuel source as determined pursuant to § 99.32(b)(1), in thousand scf.
VRICE = The total volume of natural gas combusted in reciprocating internal combustion engines with crankcase vents during the reporting year, in thousand scf.
(6) If a portion, or all, of the increased volume of natural gas resulting from methane emissions mitigation was used for another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source, equation C-6 of this section must be used to calculate the quantity of methane emissions from the use of the increased volume of natural gas resulting from methane emissions mitigation implementation.
Where:
EUse,CH4 = The quantity of methane emissions from the increased volume of natural gas resulting from methane emissions mitigation implementation used for another useful purpose that an otherwise purchased fuel or raw material would have served, excluding use as an onsite fuel source as calculated in accordance with paragraph (c)(5) of this section, mt CH4.
ELeaks-Use,CH4 = The quantity of methane emissions from equipment leaks from components involved in the useful purpose as calculated in accordance with paragraphs (c)(9)(i) through (iii) of this section, as applicable, for the reporting year, mt CH4. When determining the equipment leak emissions, use only the equipment components that were involved in the useful purpose that an otherwise purchased fuel or raw material would have served during the eligible delay.
(7) If a portion, or all, of the increased volume of natural gas resulting from methane emissions mitigation was reinjected into a well, equation C-7 of this section must be used to calculate the quantity of methane emissions from reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation.
Where:
EReinject,CH4 = The total quantity of methane emissions from reinjection into a well of increased volume of natural gas resulting from methane emissions mitigation implementation, mt CH4.
ECent,CH4 = The total quantity of methane emissions from centrifugal compressors, mt CH4. For reporting year 2024, use the sum total of the values reported to § 98.236(o)(2)(ii)(D)(2) and (o)(5)(iii) of this chapter for the WEC applicable facility. For reporting year 2025 and later, use the sum total of the values reported to § 98.236(o)(2)(ii)(D)(2) and (o)(5)(iv) of this chapter for the well-pad site.
CountCent,Reinject = The count of centrifugal compressors used in the reinjection into wells of natural gas resulting from methane emissions mitigation implementation. For reporting year 2024, use the count associated with the WEC applicable facility for the reporting year. For reporting year 2025 and later, use the count associated with the well-pad site for the reporting year.
CountCent,Total = The total count of centrifugal compressors reported pursuant to § 98.236(o)(1) of this chapter. For reporting year 2024, use the quantity reported at the WEC applicable facility for the reporting year. For reporting year 2025 and later, use the quantity reported for the well-pad site.
ERecip,CH4 = The total quantity of methane emissions from reciprocating compressors, mt CH4. For reporting year 2024, use the sum total of the values reported to § 98.236(p)(2)(ii)(D)(2) and (p)(5)(iii) of this chapter for the WEC applicable facility. For reporting year 2025 and later, use the sum total of the values reported to § 98.236(p)(2)(ii)(D)(2) and (p)(5)(iv) of this chapter for the well-pad site.
CountRecip,Reinject = The count of reciprocating compressors used in the reinjection into wells of natural gas resulting from methane emissions mitigation implementation. For reporting year 2024, use the count associated with the WEC applicable facility for the reporting year. For reporting year 2025 and later, use the count associated with the well-pad site.
CountRecip,Total = The total count of reciprocating compressors reported pursuant to § 98.236(o)(1) of this chapter. For reporting year 2024, use the quantity reported at the WEC applicable facility for the reporting year. For reporting year 2025 and later, use the quantity reported for the well-pad site.
Td = The time period associated with the eligible delay within the reporting year, as determined pursuant to § 99.32(a), in days.
T = The number of days in the reporting year. Use 365, or for leap years, 366.
ELeaks-Reinject,CH4 = The quantity of methane emissions from equipment leaks from components involved in reinjection as calculated in accordance with paragraph (c)(9)(i) through (iii) of this section, as applicable, for the reporting year, mt CH4. When determining the equipment leaks use only the equipment components that were involved in reinjection during the eligible delay.
(8) If a portion, or all, of the increased volume of natural gas resulting from methane emissions mitigation was flared, equation C-8A of this section must be used to calculate the quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation for each associated flare. For reporting year 2024, if a CEMS was used to measure emissions from an associated flare as reported to § 98.236(n)(12) of this part, do not determine methane emissions for that flare. Equation C-8B of this section must be used to calculate the quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation for the WEC applicable facility or well-pad site, as applicable.
Where:
EFlare,i,CH4 = The quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation for an individual flare, mt CH4.
VFlared = The volume of natural gas resulting from methane emissions mitigation implementation that was flared at the flare as determined pursuant to § 98.32(b)(4)(ii) or (iii) of this chapter, as applicable, scf.
XCH4 = Mole fraction of CH4 in the gas sent to the flare. For reporting year 2024, use the value reported to § 98.236(n)(7) of this chapter. For reporting year 2025 and later, if you determine composition of each stream routed to the flare as specified in § 98.233(n)(4)(iii) of this chapter and the stream or combination of streams contain only the flow resulting from methane emissions mitigation implementation, use the mole fraction as reported to § 98.236(n)(14) of this chapter (if using multiple streams, use the flow-weighted average mole fraction). Otherwise, for reporting year 2025 and later, use the average mole fraction of CH4 in produced gas for the sub-basin in which the well-pad site at which methane emissions mitigation implementation occurred as reported to § 98.236(aa)(1)(ii)(I) of this chapter.
O = Flare destruction efficiency for the flare. For reporting year 2024, use the flare combustion efficiency reported to § 98.236(n)(6) of this chapter. For reporting year 2025 and later, use the flare destruction efficiency reported to § 98.236(n)(13) of this chapter.
ZL = Fraction of the feed gas sent to the burning flare, equal to 1—ZU of this section.
ZU = Fraction of the feed gas sent to the flare when it was un-lit. For reporting year 2024, use the value reported to § 98.236(n)(5) of this chapter. For reporting year 2025 and later, use the value reported to § 98.236(n)(12) of this chapter.
ρCH4 = Density of methane at 60 °F and 14.7 psia. Use 0.0192 kg/ft
3.
10−3 = Conversion from kilograms to metric tons.
Where:
EFlare,CH4 = The quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation, mt CH4.
EFlare,i,CH4 = The quantity of methane emissions from flaring of increased volume of natural gas resulting from methane emissions mitigation implementation for each associated flare, i, as determined using equation C-8A of this section, mt CH4.
M = Total number of flares that received an increased volume of gas resulting from methane emissions mitigation implementation.
(9) You must quantify equipment leak methane emissions from components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation at the WEC applicable facility in accordance with the methods in paragraphs (c)(9)(i) through (iii) of this section. You must use the same calculation method for equipment leaks reported pursuant to § 98.236(q) or (r) of this chapter in the part 98 report associated with the components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation at the WEC applicable facility.
(i) If equipment leak surveys and measurement were used to quantify methane emissions from components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation and reported pursuant to § 98.236(q) of this chapter in the part 98 report for a WEC applicable facility, you must calculate the methane emissions (i.e., EMeasured Leak, CH4) for each leak in accordance with equation C-9A of this section. The sum of the quantified methane emissions from components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation calculated in accordance with equation C-9A of this section shall be considered “ELeaks-Use, CH4” and “ELeaks-Reinject, CH4” in Equations C-6 and C-7 of this section, as applicable.
Where:
EMeasured Leak,CH4 = The quantity of methane emissions attributable to a measured leak emissions from components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation, mt CH4.
p = Component type as reported in accordance with § 98.236(q) of this chapter, as applicable.
z = An individual component involved in the useful purpose or reinjection of type “p” detected as leaking and measured any leak survey during the year.
Qp,z = Volumetric flow rate of the natural gas leak for component “z” of component type “p” converted to standard conditions according to § 98.233(q)(3)(iii) of this chapter, scf whole gas/hour/component, as applicable.
MCH4 = The mole fraction of CH4 in produced gas for the well. For onshore petroleum and natural gas production wells, use the mole fraction of CH4 in produced gas for the sub-basin associated with the well, as reported pursuant to § 98.236(aa)(1)(ii)(I) of this chapter, unitless. For RY2024, if multiple sub-basins were impacted by the unreasonable delay, use the flow-weighted average mole fraction.
Tp,z = The total time the surveyed component “z” of component type “p” was assumed to be leaking. If one leak detection survey is conducted in the calendar year, assume the component was leaking from the beginning of the delay period as determined in accordance with § 99.32(a)(1) until the date the delay ended as determined in accordance with § 99.32(a)(2), days. If multiple leak detection surveys are conducted in the calendar year, assume a component found leaking in the first survey was leaking since the beginning of the year until the date of the survey; assume a component found leaking in the last survey of the year was leaking from the preceding survey through the date the delay ended as determined in accordance with § 99.32(a)(2), days; assume a component found leaking in a survey between the first and last surveys of the year was leaking since the preceding survey until the date of the survey, days; and sum times for all leaking periods. For each leaking component, account for time the component was not operational (i.e., not operating under pressure) using an engineering estimate based on best available data.
k = The factor to adjust for undetected leaks by respective leak detection method. For reporting year 2024, k equals 1. For reporting year 2025 and later, k equals 1.25 for the methods in § 98.234(a)(1), (3) and (5) of this chapter; k equals 1.55 for the method in § 98.234(a)(2)(i) of this chapter; and k equals 1.27 for the method in § 98.234(a)(2)(ii) of this chapter. Select the factor for the leak detection method used for the permanently shut-in and plugged well, unitless.
ρCH4 = Density of methane, 0.0192 mt/Mscf.
10−3 = Conversion factor from scf to Mscf.
(ii) If equipment leak surveys were used to quantify methane emissions from components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation and reported pursuant to § 98.236(q) of this chapter in the part 98 report for a WEC applicable facility, equation C-9B of this section must be used to calculate ELeaks,CH4.
Where:
ELeaks,CH4 = The annual quantity of methane emissions attributable to components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation as reported pursuant to § 98.236(q) of this chapter for the reporting year, mt CH4.
p = Component type as specified in § 98.233(q)(2)(iii) of this chapter.
Np = The number of component types with detected leaks involved in the useful purpose or reinjection.
EFp = The leaker emission factor for component “p” as specified in § 98.233(q)(2)(iii) of this chapter, scf whole gas/hour/component.
24 = Conversion from days to hours.
MCH4 = The mole fraction of CH4 in produced gas for the sub-basin in which the useful purpose or reinjection occurred, as reported pursuant to § 98.236(aa)(1)(ii)(I) of this chapter, unitless. For RY2024, if multiple sub-basins were impacted by the unreasonable delay, use the flow-weighted average mole fraction.
xp = The total number of specific components involved in the useful purpose or reinjection of type “p” detected as leaking during the year. A component found leaking in two or more surveys during the year is counted as one leaking component.
Tp,z = The total time the surveyed component “z” of component type “p” was assumed to be leaking. If one leak detection survey is conducted in the calendar year, assume the component was leaking from the beginning of the delay period as determined in accordance with § 99.32(a)(1) until the date the delay ended as determined in accordance with § 99.32(a)(2), days. If multiple leak detection surveys are conducted in the calendar year, assume a component found leaking in the first survey was leaking since the beginning of the year until the date of the survey; assume a component found leaking in the last survey of the year was leaking from the preceding survey through the date the delay ended as determined in accordance with § 99.32(a)(2), days; assume a component found leaking in a survey between the first and last surveys of the year was leaking since the preceding survey until the date of the survey, days; and sum times for all leaking periods. For each leaking component, account for time the component was not operational (i.e., not operating under pressure) using an engineering estimate based on best available data.
k = The factor to adjust for undetected leaks by respective leak detection method. For reporting year 2024, k equals 1. For reporting year 2025 and later, k equals 1.25 for the methods in § 98.234(a)(1), (3) and (5) of this chapter; k equals 1.55 for the method in § 98.234(a)(2)(i) of this chapter; and k equals 1.27 for the method in § 98.234(a)(2)(ii) of this chapter. Select the factor for the leak detection method used for the permanently shut-in and plugged well, unitless.
ρCH4 = Density of methane, 0.0192 mt/Mscf.
10−3 = Conversion factor from scf to Mscf.
(iii) If equipment leaks by population count were used to quantify methane emission from components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation and reported pursuant to § 98.236(r) of this chapter in the part 98 report for a WEC applicable facility, equation C-9C of this section must be used to calculate ELeaks,CH4.
Where:
ELeaks,CH4 = The annual quantity of methane emissions attributable to components involved in the useful purpose or reinjection of the increased volume of natural gas resulting from methane emissions mitigation implementation as reported pursuant to § 98.236(r) of this chapter for the reporting year, mt CH4.
Countp = For each component type, “p”, listed in § 98.233(r)(2) of this chapter that was involved in the useful purpose or reinjection, count the number of components of that type.
EFp = The population emission factor for the component type, “p”, as listed in § 98.233(r)(2) of this chapter.
MCH4 = The mole fraction of CH4 in produced gas for the sub-basin in which the useful purpose or reinjection occurred, as reported pursuant to § 98.236(aa)(1)(ii)(I) of this chapter, unitless. For RY2024, if multiple sub-basins were impacted by the unreasonable delay, use the flow-weighted average mole fraction.
T = The time period of the eligible delay within the reporting year, as determined in accordance with § 99.32(a), days.
24 = Conversion from days to hours.
ΡCH4 = Density of methane, 0.0192 mt/Mscf.
10−3 = Conversion factor from scf to Mscf.