Q813. What are the optional delayed reporting requirements for wildcat wells and delineation wells?

A813. Subpart W specifies that reporting may be delayed by up to two years for certain data elements that are based exclusively on information from wildcat wells or delineation wells. The specific requirements differ for each reporting year. Details of the requirements for each year are described below:

  1. Reporting Year 2015. Beginning with reporting year 2015, there are 12 data elements for which reporting may be delayed by 2 years in situations where the data are derived exclusively from wildcat wells and/or delineation wells. The 12 data elements are:
    • For each sub-basin with gas well completions/workovers with hydraulic fracturing, the cumulative flowback time (40 CFR 98.236(g)(5)(i));
    • For each sub-basin with gas well completions/workovers with hydraulic fracturing, the flowback rate for the measured well(s) (40 CFR 98.236(g)(5)(ii));
    • For each sub-basin with gas well completions without hydraulic fracturing and without flaring, average daily gas production rate for all completions without hydraulic fracturing in the sub-basin without flaring (40 CFR 98.236(h)(1)(iv));
    • For each sub-basin with gas well completions without hydraulic fracturing and with flaring, average daily gas production rate for all completions without hydraulic fracturing in the sub-basin with flaring (40 CFR 98.236(h)(2)(iv));
    • At the sub-basin level for atmospheric tanks where emissions were calculated using Calculation Method 1 or 2, the total annual oil volume that is sent to atmospheric storage tanks (40 CFR 98.236(j)(1)(iii));
    • At the basin level for atmospheric tanks where emissions were calculated using Calculation Method 3, the total annual oil throughput that is sent to atmospheric tanks in the basin (40 CFR 98.236(j)(2)(i)(A));
    • If oil well testing is performed where emissions are not vented to a flare, the average flow rate in barrels of oil per day for well(s) tested (40 CFR 98.236(l)(1)(iv);
    • If oil well testing is performed where emissions are vented to a flare, the average flow rate in barrels of oil per day for well(s) tested (40 CFR 98.236(l)(2)(iv));
    • If gas well testing is performed where emissions are not vented to a flare, average annual production rate in actual cubic feet per day for well(s) tested (40 CFR 98.236(l)(3)(iii));
    • If gas well testing is performed where emissions are vented to a flare, average annual production rate in actual cubic feet per day for well(s) tested. (40 CFR 98.236(l)(4)(iii));
    • Volume of oil produced in the calendar year during the time periods in which associated gas was vented or flared (40 CFR 98.236(m)(5)); and
    • Total volume of associated gas sent to sales in the calendar year during time periods in which associated gas was vented or flared (40 CFR 98.236(m)(6)).

In the annual report for reporting year 2015, reporters that elect to comply with the delayed reporting option must indicate in the annual report for reporting year 2015 (i.e., by March 31, 2016) that one of the following situations is true for each of the data elements for which reporting is to be delayed:

    • For gas well completions or workovers with hydraulic fracturing, wildcat wells and/or delineation wells are the only wells in a sub-basin that can be used for the measurement;
    • For gas well completions without hydraulic fracturing, wildcat wells and/or delineation wells are the only wells in a sub-basin that can be used for the measurement;
    • For onshore production storage tanks, wildcat wells and/or delineation wells are the only wells in a sub-basin or basin;
    • For well testing, wildcat wells and/or delineation wells are the only wells in a sub-basin that are tested;
    • For associated gas venting and flaring, wildcat wells and/or delineation wells are the only wells in a sub-basin.

All of the delayed reporting data elements for reporting year 2015 must be reported by March 31, 2018. In addition, the well ID numbers for the applicable wildcat and/or delineation wells associated with each delayed reporting data element must be reported by March 31, 2018.


2. Reporting Years 2016 through 2024. Beginning with reporting year 2016, there are 14 data elements for which reporting may be delayed by 2 years in situations where the data are derived exclusively from wildcat wells and/or delineation wells. The 14 data elements are:

    • For each sub-basin with oil or gas well completions/workovers with hydraulic fracturing, the cumulative flowback time (40 CFR 98.236(g)(5)(i));
    • For each sub-basin with oil or gas well completions/workovers with hydraulic fracturing, the flowback rate for the measured well(s) (40 CFR 98.236(g)(5)(ii));
    • For each sub-basin with oil or gas well completions/workovers with hydraulic fracturing, the gas to oil ratio in standard cubic feet of gas per barrel of oil if using Equation W-12C to calculate the average gas production rate for an oil well (40 CFR 98.236(g)(5)(iii)(A));
    • For each sub-basin with oil or gas well completions/workovers with hydraulic fracturing, the volume of oil produced for the well in standard cubic feet of gas per barrel of oil if using Equation W-12C to calculate the average gas production rate for an oil well (40 CFR 98.236(g)(5)(iii)(B));
    • For each sub-basin with gas well completions without hydraulic fracturing and without flaring, average daily gas production rate for all completions without hydraulic fracturing in the sub-basin without flaring (40 CFR 98.236(h)(1)(iv));
    • For each sub-basin with gas well completions without hydraulic fracturing and with flaring, average daily gas production rate for all completions without hydraulic fracturing in the sub-basin with flaring (40 CFR 98.236(h)(2)(iv));
    • At the sub-basin level for atmospheric tanks where emissions were calculated using Calculation Method 1 or 2, the total annual oil volume that is sent to atmospheric storage tanks (40 CFR 98.236(j)(1)(iii));
    • At the basin level for atmospheric tanks where emissions were calculated using Calculation Method 3, the total annual oil throughput that is sent to atmospheric tanks in the basin (40 CFR 98.236(j)(2)(i)(A));
    • If oil well testing is performed where emissions are not vented to a flare, the average flow rate in barrels of oil per day for well(s) tested (40 CFR 98.236(l)(1)(v);
    • If oil well testing is performed where emissions are vented to a flare, the average flow rate in barrels of oil per day for well(s) tested (40 CFR 98.236(l)(2)(v));
    • If gas well testing is performed where emissions are not vented to a flare, average annual production rate in actual cubic feet per day for well(s) tested (40 CFR 98.236(l)(3)(iv));
    • If gas well testing is performed where emissions are vented to a flare, average annual production rate in actual cubic feet per day for well(s) tested. (40 CFR 98.236(l)(4)(iv));
    • Volume of oil produced in the calendar year during the time periods in which associated gas was vented or flared (40 CFR 98.236(m)(5)); and
    • Total volume of associated gas sent to sales in the calendar year during time periods in which associated gas was vented or flared (40 CFR 98.236(m)(6)).

In the annual report for the applicable reporting year, reporters that elect to comply with the delayed reporting option must indicate in the annual report for that reporting year (i.e., by March 31 of the following year) that one of the following situations is true for each of the data elements for which reporting is to be delayed:

    • For gas well oil or gas well completions or workovers with hydraulic fracturing, wildcat wells and/or delineation wells are the only wells in a sub-basin that can be used for the measurement;
    • For gas well completions without hydraulic fracturing, wildcat wells and/or delineation wells are the only wells in a sub-basin that can be used for the measurement;
    • For onshore production storage tanks, wildcat wells and/or delineation wells are the only wells in a sub-basin or basin;
    • For well testing, wildcat wells and/or delineation wells are the only wells in a sub-basin that are tested;
    • For associated gas venting and flaring, wildcat wells and/or delineation wells are the only wells in a sub-basin.

All of the delayed reporting data elements for the reporting year for which the delay is claimed must be reported in the annual report two years following. For example, delayed data elements claimed for the 2024 reporting year, must be reported by March 31, 2025. In addition, the well ID numbers for the applicable wildcat and/or delineation wells associated with each delayed reporting data element must be reported by the required date.


3. Reporting Year 2025 and future years. Beginning with reporting year 2025, there are 30 data elements for which reporting may be delayed by 2 years in situations where the data are derived exclusively from wildcat wells and/or delineation wells. In addition, beginning in 2025, reporting for the Onshore Petroleum and Natural Gas Production industry segment will change from the basin and sub-basin level to the well, well-pad site and facility levels depending on the source and calculation method. The 30 data elements are:

    • For each well with oil or gas well completions/workovers with hydraulic fracturing, the cumulative flowback time for all completions or workovers at the well (40 CFR 98.236(g)(5)(i));
    • For each sub-basin with oil or gas well completions/workovers with hydraulic fracturing, the flowback rate for the measured well (40 CFR 98.236(g)(5)(ii));
    • For each well with oil or gas well completions/workovers with hydraulic fracturing, gas to oil ratio for the well in standard cubic feet of gas per barrel of oil if using Equation W-12C to calculate the average gas production rate for an oil well (40 CFR 98.236(g)(5)(iii)(A));
    • For each well with oil or gas well completions/workovers with hydraulic fracturing, volume of oil produced for the well in standard cubic feet of gas per barrel of oil if using Equation W-12C to calculate the average gas production rate for an oil well (40 CFR 98.236(g)(5)(iii)(B));
    • For each well with gas well completions without hydraulic fracturing and without flaring, total number of hours that gas vented directly to the atmosphere for all completions without hydraulic fracturing and without flaring (40 CFR 98.236(h)(1)(iii));
    • For each well with gas well completions without hydraulic fracturing and without flaring, average daily gas production rate for all completions without hydraulic fracturing and without flaring (40 CFR 98.236(h)(1)(iv));
    • For each well with gas well completions without hydraulic fracturing and with flaring, total number of hours that gas routed to a flare for all completions without hydraulic fracturing and with flaring (40 CFR 98.236(h)(2)(iii));
    • For each well with gas well completions without hydraulic fracturing and with flaring, average daily gas production rate for all completions without hydraulic fracturing and with flaring (40 CFR 98.236(h)(2)(iv));
    • At the well-pad level for atmospheric tanks where emissions were calculated using Calculation Method 1 or 2, the total annual hydrocarbon liquids or produced water volume that is sent to atmospheric storage tanks on the well-pad (40 CFR 98.236(j)(1)(iii));
    • At the facility level for atmospheric tanks where emissions were calculated using Calculation Method 3, the total annual hydrocarbon liquids throughput that is sent to atmospheric tanks in the facility (40 CFR 98.236(j)(2)(i)(A));
    • If oil well testing is performed where emissions are not routed to a flare, the average gas to oil ratio per barrel of oil for each well tested (40 CFR 98.236(l)(1)(iv);
    • If oil well testing is performed where emissions are not routed to a flare, the average flow rate in barrels of oil per day for each well tested (40 CFR 98.236(l)(1)(v);
    • If oil well testing is performed where emissions are routed to a flare, the average gas to oil ratio per barrel of oil for each well tested (40 CFR 98.236(l)(2)(iv));
    • If oil well testing is performed where emissions are routed to a flare, the average flow rate in barrels of oil per day for each well tested (40 CFR 98.236(l)(2)(v));
    • If gas well testing is performed where emissions are not routed to a flare, number of well testing days for each well tested (40 CFR 98.236(l)(3)(iii));
    • If gas well testing is performed where emissions are not routed to a flare, average annual production rate in actual cubic feet per day for each well tested (40 CFR 98.236(l)(3)(iv));
    • If gas well testing is performed where emissions are routed to a flare, number of well testing days for each well tested. (40 CFR 98.236(l)(4)(iii));
    • If gas well testing is performed where emissions are routed to a flare, average annual production rate in actual cubic feet per day for each well tested. (40 CFR 98.236(l)(4)(iv));
    • Volume of oil produced by the well in the calendar year only during the time periods in which associated gas was vented or flared (40 CFR 98.236(m)(5));
    • Total volume of associated gas sent to sales or used on site and not sent to a vent or flare from each well in the calendar year only during time periods in which associated gas was vented or flared (40 CFR 98.236(m)(6));
    • If drilling mud degassing emissions are calculated using Calculation Method 1, total time that drilling mud is circulated in the well in minutes if the well is a wildcat or delineation well or if one or more wells to which the representative well CH4 emissions rate is applied is a wildcat or delineation well (40 CFR 98.236(dd)(1)(iv));
    • If drilling mud degassing emissions are calculated using Calculation Method 1, average mud rate in gallons per minute in the well if one or more wells to which the representative well CH4 emissions rate is applied is a wildcat or delineation well (40 CFR 98.236(dd)(1)(vii)(A));
    • If drilling mud degassing emissions are calculated using Calculation Method 1, average concentration of natural gas in the drilling mud for the well is a wildcat or delineation well (40 CFR 98.236(dd)(1)(vii)(B));
    • If drilling mud degassing emissions are calculated using Calculation Method 1, measured mole fraction for CH4 entrained in the drilling mud of the well if the well is wildcat or delineation well (40 CFR 98.236(dd)(1)(vii)(C));
    • If drilling mud degassing emissions are calculated using Calculation Method 1, calculated CH4 emissions rate if one or more wells to which the representative well CH4 emissions rate is applied is a wildcat or delineation well (40 CFR 98.236(dd)(1)(vii)(D));
    • If drilling mud degassing emissions are calculated using Calculation Method 3, total time that drilling mud is circulated in the well in minutes if the well is a wildcat or delineation well or if one or more wells to which the representative well CH4 emissions rate is applied is a wildcat or delineation well (40 CFR 98.236(dd)(3)(ii)(C));
    • If drilling mud degassing emissions are calculated using Calculation Method 3, average mud rate in gallons per minute in the well if one or more wells to which the representative well CH4 emissions rate is applied is a wildcat or delineation well (40 CFR 98.236(dd)(3)(ii)(F));
    • If drilling mud degassing emissions are calculated using Calculation Method 3, average concentration of natural gas in the drilling mud for the well is a wildcat or delineation well (40 CFR 98.236(dd)(3)(ii)(F)(2));
    • If drilling mud degassing emissions are calculated using Calculation Method 3, measured mole fraction for CH4 entrained in the drilling mud of the well if the well is wildcat or delineation well (40 CFR 98.236(dd)(3)(ii)(F)(3)); and
    • If drilling mud degassing emissions are calculated using Calculation Method 3, calculated CH4 emissions rate if one or more wells to which the representative well CH4 emissions rate is applied is a wildcat or delineation well (40 CFR 98.236(dd)(3)(ii)(F)(4)).

In the annual report for the applicable reporting year, reporters that elect to comply with the delayed reporting option must indicate in the annual report for that reporting year (i.e., by March 31 of the following year) that one of the following situations is true for each of the data elements for which reporting is to be delayed:

    • For gas well oil or gas well completions or workovers with hydraulic fracturing, the well is a wildcat well or delineation well;
    • For gas well completions without hydraulic fracturing, the well is a wildcat well or delineation well;
    • For onshore production storage tanks, wildcat wells and/or delineation wells are the only wells on the well-pad or in the facility;
    • For well testing, the tested well is a wildcat well or delineation well;
    • For associated gas venting and flaring, the well is a wildcat well or delineation well;
    • For drilling mud degassing, the well is a wildcat and/or delineation well or if one or more wells for which the CH4 emissions rate of the representative well is applied are wildcat and/or delineation wells.

All of the delayed reporting data elements for the reporting year for which the delay is claimed must be reported in the annual report two years following. For example, delayed data elements claimed for the 2025 reporting year, must be reported by March 31, 2026. In addition, the well ID numbers for the applicable wildcat and/or delineation wells associated with each delayed reporting data element must be reported by the required date.

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