# Appendix A to the 2015 Supporting Statement for Sub part W

Dated November 2014

New Subpart W Reporting ElementsEmission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionNatural Gas PneumaticDevices§98.236(b)(1)(i) The total number of devices, determined according to §98.233(a)(1) and (a)(2). 1Natural Gas PneumaticDevices§98.236(b)(1)(ii)(A) A list of the well ID numbersassociated with the devices that are counted (for the onshore petroleum and naturalgas production industry segment only).1Natural Gas PneumaticDevices§98.236(b)(1)(ii)(A) The number of devices reportedin paragraph (b)(1)(i) of this section that are counted. 1Natural Gas PneumaticDevices§98.236(b)(1)(ii)(B) A list of the well ID numbersassociated with the devices that are estimated (notcounted) (for the onshorepetroleum and natural gas production industry segment only).1Natural Gas PneumaticDevices§98.236(b)(1)(ii)(B) The number of devices reportedin paragraph (b)(1)(i) of this section that are estimated (not counted). 1Natural Gas PneumaticDevices§98.236(b)(1)(ii)(C) Whether the calendar year is the first calendar year of reporting or the second calendar year of reporting 1Natural Gas PneumaticDevices§98.236(b)(2) For each type of pneumatic device, the estimated average number of hours in the calendaryear that the natural gaspneumatic devices reported in paragraph (b)(1)(i) of this section were operating in the calendar year(“Tt” inEquation W-1 of this subpart).1Natural Gas PneumaticDevices§98.236(b)(3) Annual CO2emissions, in metric tons CO2, for the natural gas pneumatic devices combined, calculated usingEquation W-1 of this subpart and § 98.233(a)(4), and reported in paragraph (b)(1)(i) of this section1Natural Gas PneumaticDevices§98.236(b)(4) Annual CH4emissions, in metric tons CH4, for the natural gas pneumatic devices combined, calculated usingEquation W-1 of this subpart and § 98.233(a)(4), and reported in paragraph (b)(1)(i) of this section1Natural Gas PneumaticPump Venting§98.236(c)(1) Count of natural gas driven pneumaticpumps1Natural Gas PneumaticPump Venting§98.236(c)(2) A list of the well ID numbers associated with the natural gas driven pneumatic pumps (for the onshore petroleumand natural gas production industry segment only).1Natural Gas PneumaticPump Venting§98.236(c)(3) Average estimated number of hours inthe calendar year the pumps were operational (“T” in Equation W-2 of thissubpart)..1Natural Gas PneumaticPump Venting§98.236(c)(4) Annual CO2emissions, in metric tons CO2, for all natural gas driven pneumatic pumps combined, calculatedaccording to §98.233(c)(1) and (c)(2)1Natural Gas PneumaticPump Venting§98.236(c)(5) Annual CH4emissions, in metric tons CH4, for all natural gas driven pneumatic pumps combined, calculatedaccording to §98.233(c)(1) and (c)(2)1Acid Gas Removal §98.236(d)(1)(i) A unique name orID number for acid gas removal unit.1Acid Gas Removal §98.236(d)(1)(ii) A list of the well ID numbers associated with the acid gas removalunits (for the onshore petroleum and natural gasproduction industry segment only)..1Acid Gas Removal §98.236(d)(1)(iii) Total feed rateentering the acid gas removal unit, using a meteror engineering estimate based on processknowledge or best available data, in million cubicfeet per year.1Acid Gas Removal §98.236(d)(1)(iv) The calculationmethod used to calculate CO2emissions from the acid gas removal unit, as specified in §98.233(d). 1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionAcid Gas Removal §98.236(d)(1)(v) Whether any CO2emissions are recovered and transferred outside the facility 1Acid Gas Removal §98.236(d)(1)(v) If any CO2emissions from the acid gas removal unit were recovered and transferred outside the facility, then youmust report the annual quantity of CO2, in metric tons CO2,that was recovered and transferred outside the facility.1Acid Gas Removal §98.236(d)(1)(vi) Annual CO2emissions, in metric tons CO2, from the acid gas removal unit, calculated usingany one of thecalculation methods specified in §98.233(d) and asspecified in §98.233(d)(10) and (11).1Acid Gas Removal §98.236(d)(1)(vii) Sub-basin ID that best represents the wells and/or equipment supplying gas to the unit. 1Acid Gas Removal §98.236(d)(2)(i)(A) For each unitfor which Calculation Methodology 1 or 2 in §98.233(d) is used, annual average volumetric fractionof CO2in the vent gas exiting the acid gas removal unit.1Acid Gas Removal §98.236(d)(2)(i)(B) For each unitfor which Calculation Methodology 1 or 2 in §98.233(d) is used, annual volume of gas vented fromthe acid gas removal unit, in cubic feet.1Acid Gas Removal §98.236(d)(2)(ii)(A) For each unitfor which Calculation Methodology 3 in §98.233(d)is used, indicate which equation was used(Equation W-4A or W-4B).1Acid Gas Removal §98.236(d)(2)(ii)(B) For each unitfor which Calculation Methodology 3 in §98.233(d)is used, annual average volumetric fraction ofCO2in the natural gas flowing out of the acid gas removal unit, as specified in Equation W-4A or Equation W-4Bof this subpart.1Acid Gas Removal §98.236(d)(2)(ii)(C) For each unitfor which Calculation Methodology 3 in §98.233(d)is used, annual average volumetric fraction ofCO2content in natural gas flowing into the acid gas removal unit, as specified in Equation W-4A or Equation W4B of this subpart.1Acid Gas Removal §98.236(d)(2)(ii)(D) For each unitfor which Calculation Methodology 3 in §98.233(d)is used, the natural gas flow rate used, asspecified in Equation W-4A of this subpart, reported as either total annual volume of natural gas flowinto the acidgas removal unit in cubic feet at actual conditions; or total annual volume of natural gas flow out ofthe acid gasremoval unit, as specified in Equation W-4B of thissubpart, in cubic feet at actual conditions,.1Acid Gas Removal §98.236(d)(2)(iii)(A) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the name of the simulation softwarepackage used1Acid Gas Removal §98.236(d)(2)(iii)(B) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the natural gas feed temperature, indegrees Fahrenheit.1Acid Gas Removal §98.236(d)(2)(iii)(C) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the natural gas feed pressure, in poundsper square inch.1Acid Gas Removal §98.236(d)(2)(iii)(D) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the natural gas flow rate, in standardcubic feet per minute.1Acid Gas Removal §98.236(d)(2)(iii)(E) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the acid gas content of the feed naturalgas, in mole percent.1Acid Gas Removal §98.236(d)(2)(iii)(F) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the acid gas content of the outlet naturalgas, in mole percent.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionAcid Gas Removal §98.236(d)(2)(iii)(G) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the unit operating hours, excludingdowntime for maintenance or standby, in hours per year.1Acid Gas Removal §98.236(d)(2)(iii)(H) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the exit temperature of the natural gas,in degrees Fahrenheit.1Acid Gas Removal §98.236(d)(2)(iii)(I) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the solvent pressure, in pounds persquare inch.1Acid Gas Removal §98.236(d)(2)(iii)(J) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the solvent temperature, in degreesFahrenheit.1Acid Gas Removal §98.236(d)(2)(iii)(K) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the solvent circulation rate, in gallonsper minute.1Acid Gas Removal §98.236(d)(2)(iii)(L) For each unit for which Calculation Methodology 4 in §98.233(d)is used, the solvent weight, in pounds per gallon.1Dehydrators §98.236(e)(1)(i) Unique name or ID number for dehydrators.1Dehydrators §98.236(e)(1)(ii) For the onshore petroleum and natural gas production segment only, a list of well ID number(s) associated with thedehydrators.1Dehydrators §98.236(e)(1)(iii) Dehydrator feed natural gas flow rate, in million standard cubic feetper day, determined by engineering estimatebased on best available data.1Dehydrators §98.236(e)(1)(iv) Dehydrator feed natural gas water content, in pounds per million standard cubic feet. 1Dehydrators §98.236(e)(1)(v) Dehydrator outlet natural gas water content, in pounds per million standard cubic feet. 1Dehydrators §98.236(e)(1)(vi) Dehydrator absorbentcirculation pump type (e.g., natural gas pneumatic, air pneumatic, or electric).1Dehydrators §98.236(e)(1)(vii) Dehydrator absorbent circulation rate, in gallons per minute.1Dehydrators §98.236(e)(1)(viii) Type of absorbent(e.g., triethylene glycol (TEG), diethylene glycol(DEG), or ethylene glycol (EG)).1Dehydrators §98.236(e)(1)(ix) Whether stripper gasis used in dehydrator.1Dehydrators §98.236(e)(1)(x) Whether a flash tankseparator is used in dehydrator.1Dehydrators §98.236(e)(1)(xi) Total time the dehydrator is operating, in hours.1Dehydrators §98.236(e)(1)(xii) Temperature of thewet natural gas, in degrees Fahrenheit.1Dehydrators §98.236(e)(1)(xiii) Pressure of the wet natural gas, in pounds per square inch gauge.1Dehydrators §98.236(e)(1)(xiv) Mole fraction of CH4in wet natural gas.1Dehydrators §98.236(e)(1)(xv) Mole fraction of CO2in wet natural gas.1Dehydrators §98.236(e)(1)(xvi) For each glycol dehydrator, whether any dehydrator emissions are vented to the atmosphere without being routedto a flare or regenerator firebox.1Dehydrators §98.236(e)(1)(xvii) Whether any dehydrator emissions are vented to a flare or regeneratorfirebox/fire tubes. 1Dehydrators §98.236(e)(1)(xvii)(A) If any emissions are vented to a flare or regenerator firebox/firetubes, annual CO2emissions, in metric tons CO2,for the dehydrator, calculated according to § 98.233(e)(6).1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionDehydrators §98.236(e)(1)(xvii)(B) If any emissions are vented to a flare or regenerator firebox/firetubes, annual CH4emissions, in metric tons CH4,for the dehydrator, calculated according to § 98.233(e)(6).1Dehydrators §98.236(e)(1)(xvii)(C) If any emissions are vented to a flare or regenerator firebox/firetubes, annual N2O emissions, in metric tons N2O,for the dehydrator, calculated according to § 98.233(e)(6).1Dehydrators §98.236(e)(1)(xviii) For each glycol dehydrator, whether any dehydrator emissions are vented to the atmosphere without being routedto a flare or regenerator firebox.1Dehydrators §98.236(e)(1)(xviii)(A) If any emissions are not routed to a flare or regenerator firebox/fire tubes, annual CO2emissions, in metric tonsCO2, for the dehydrator when not venting to a flare orregenerator firebox/fire tubes, calculated according to §98.233(e)(1) and (e)(5).1Dehydrators §98.236(e)(1)(xviii)(B) If any emissions are not routed to a flare or regenerator firebox/fire tubes, annual CH4emissions, in metric tonsCH4, for the dehydrator when not venting to a flare orregenerator firebox/fire tubes, calculated according to §98.233(e)(1) and (e)(5).1Dehydrators §98.236(e)(1)(xix) For each glycol dehydrator, sub-basin ID that best represents the wells and/or equipment supplying gas to thedehydrator.1Dehydrators §98.236(e)(2)(i) The total number of glycol dehydrators at the facility with an annual average daily natural gas throughput less than0.4 million standard cubic feet per day.1Dehydrators §98.236(e)(2)(ii) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers associated withthe dehydrators at the facility.1Dehydrators §98.236(e)(2)(iii) For the onshore petroleum and natural gas production segment only, a list of the associated well ID numbers forglycol dehydrators at the facility that were ventedto a vapor recovery device.1Dehydrators §98.236(e)(2)(iii) For the onshore petroleum and natural gas production industry segment only, a list of the associated well IDnumbers for each glycol dehydrator at the facilitythat was vented to a vapor recovery device.1Dehydrators §98.236(e)(2)(iv) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd, the number ofdehydrators venting to a control device other thana vapor recovery device or a flare or regenerator firebox/firetubes.1Dehydrators §98.236(e)(2)(iv) For the onshore petroleum and natural gas production segment only, a list of the associated well ID numbers foreach type of control device (other than a vapor recovery device, flare, or regenerator firebox/fire tubes) to which aglycol dehydrator at the facility was vented.1Dehydrators §98.236(e)(2)(v) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd, whether anyglycol dehydrator emissions are vented to a flare or regenerator firebox/fire tubes.1Dehydrators §98.236(e)(2)(v)(A) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd and vent to aflare or regenerator firebox, the total number of dehydrators.1Dehydrators §98.236(e)(2)(v)(B) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd and vent to aflare or regenerator firebox, annual CO2emissions, in metric tons CO2, for the dehydrators reported in paragraph(e)(2)(iv)(A) of this section, calculated accordingto § 98.233(e)(6).1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionDehydrators §98.236(e)(2)(v)(C) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd and vent to aflare or regenerator firebox, annual CH4emissions, in metric tons CH4, for the dehydrators reported in paragraph(e)(2)(iv)(A) of this section, calculated accordingto § 98.233(e)(6).1Dehydrators §98.236(e)(2)(v)(D) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd and vent to aflare or regenerator firebox, annual N2O emissions, in metric tons N2O, for the dehydrators reported in paragraph(e)(2)(iv)(A) of this section, calculated accordingto § 98.233(e)(6).1Dehydrators §98.236(e)(2)(vi)(A) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd not vented to aflare or regenerator firebox/fire tubes, annual CO2emissions in metric tons CO2, for emissions from all dehydratorsreported in paragraph (e)(2)(i) of this section that were not vented to a flare or regenerator firebox/fire tubes,calculated according to § 98.233(e)(2), (e)(4), and(e)(5), where emissions are added together for allsuchdehydrators.1Dehydrators §98.236(e)(2)(vi)(B) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 MMscfd not vented to aflare or regenerator firebox/fire tubes, annual CH4emissions in metric tons CO2, for emissions from all dehydratorsreported in paragraph (e)(2)(i) of this section that were not vented to a flare or regenerator firebox/fire tubes,calculated according to § 98.233(e)(2), (e)(4), and(e)(5), where emissions are added together for allsuchdehydrators.1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant, the total number of dehydrators at the facility. 1Dehydrators §98.236(e)(3)(i) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers associated withthe dehydrators using desiccant at the facility.1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant, the total number of dehydrators venting to a vapor recovery device. 1Dehydrators §98.236(e)(3)(i) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers associated withthe dehydrators using desiccant and venting to a vapor recovery device at the facility.1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant, the number of dehydrators venting toa control device other than a vaporrecovery device or a flare or regenerator firebox/fire tubes.1Dehydrators §98.236(e)(3)(i) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers associated withthe dehydrators at the facility using desiccant andventing to a control device other than a vapor recovery device ora flare or regenerator firebox/fire tubes.1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant and vent to a flare or regenerator firebox, the total number of dehydrators. 1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant and vent to a flare or regenerator firebox, annual CO2emissions, in metric tonsCO2, for the dehydrators reported in paragraph (e)(2)(iv)(A) of this section, calculated according to § 98.233(e)(6).1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant and vent to a flare or regenerator firebox, annual CH4emissions, in metric tonsCH4, for the dehydrators reported in paragraph (e)(2)(iv)(A) of this section, calculated according to § 98.233(e)(6).1Dehydrators §98.236(e)(3)(i) For dehydrators thatuse desiccant and vent to a flare or regenerator firebox, annual N2O emissions, in metric tonsN2O, for the dehydrators reported in paragraph (e)(2)(iv)(A) of this section, calculated according to §98.233(e)(6).1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionDehydrators §98.236(e)(3)(ii) Annual CO2emissions, in metric tons CO2, for emissions from all desiccant dehydrators reported under paragraph(e)(3)(i) of this section that are not venting to aflare or regenerator firebox/fire tubes, calculated according to §98.233(e)(3), (e)(4), and (e)(5), and summing for all such dehydrators.1Dehydrators §98.236(e)(3)(iii) Annual CH4emissions, in metric tons CH4, for emissions from all desiccant dehydrators reported in paragraph(e)(3)(i) of this section that are not venting to aflare or regenerator firebox/fire tubes, calculated according to §98.233(e)(3), (e)(4), and (e)(5), and summing for all such dehydrators.1Liquids Unloading §98.236(f)(1)(ii) A list of the well ID numbers associated with each sub-basin welltubing diameter and pressure group ID for whichyou used Calculation Method 1 to calculate naturalgas emissions from well venting for liquids unloading.1Liquids Unloading §98.236(f)(2)(i) A list of the well ID numbers associated with each sub-basin for which you used Calculation Method 2 or 3 tocalculate natural gas emissions from well venting for liquids unloading.1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g) Whether the facility had any oil well completions or workovers with hydraulic fracturing inthe calendar year. 1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(1) For each completion or workover and well type combination, the sub-basin ID. 1Completions andWorkovers withHydraulic Fracturing -Gas and Oil Wells§98.236(g)(1) A list of the well ID numbers associated with each sub-basin that had completions or workovers with hydraulicfracturing during the calendar year1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(2) For each completion or workover and well type combination, the well type (horizontal orvertical, gas well or oilwell).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(3) For each oil well completion or workover and well type combination, the total number ofcompletions orworkovers in the sub-basin and well type combination category.1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(4) For each oil well completion or workover and well type combination, the calculation method used. 1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionCompletions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(5)(i) If you used Equation W-10A to calculate annual volumetric total gas emissions, the cumulative gas flowback time,in hours, for each sub-basin, from when gas is first detected until sufficient quantities are presentto enableseparation (sum of “Tp,i” in Equation W-10A).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(5)(i) If you used Equation W-10A to calculate annual volumetric total gas emissions, the cumulative flowback time, inhours, for each sub-basin, after sufficient quantities of gas are present to enable separation (sum of“Tp,s” inEquation W-10A).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(5)(ii) If you used Equation W-10A to calculate annual volumetric total gas emissions, the measured flowback rate for themeasured well(s), in standard cubic feet per hour,for each sub-basin (average of “FRs,p” in Equation W-12A).1Completions andWorkovers withHydraulic Fracturing -Gas and Oil Wells§98.236(g)(5)(ii) The well ID numbers of the wellsfor which flowback rate is measured.1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(5)(iii)(A) If you used Equation W-12C tocalculate the average gas production rate for an oil well, the gas to oil ratio for thewell in standard cubic feet of gas per barrel of oil (“GORp” in Equation W-12C).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(5)(iii)(B) If you used Equation W-12C tocalculate the average gas production rate for an oil well, the volume of oilproduced during the first 30 days of production after completions of each newly drilled well or well workoverusing hydraulic fracturing, in barrels (“Vp” in Equation W-12C).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(6)(i) If you used Equation W-10B to calculate annual volumetric total gas emissions for completions that vent gas to theatmosphere, the vented natural gas volume, in standard cubic feet per hour, for each well in the sub-basin (“FVs,p”in Equation W-10B).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(6)(ii) If you used Equation W-10B to calculate annual volumetric total gas emissions for completions that vent gas to theatmosphere, the flow rate, in standard cubic feet per hour, at the beginning of the period of time when sufficientquantities of gas are present to enable separation(“FRp,i” in Equation W-10B).1Completions andWorkovers withHydraulic Fracturing -Gas and Oil Wells§98.236(g)(6)(iii) If you used Equation W-10B to calculate annual volumetric total gas emissions for completions that vent gas to theatmosphere, the well ID number for which vented natural gas volume was measured.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionCompletions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(7) For each oil well completion or workover and well type combination, annual gas emissions, in standard cubic feet(“Es,n” in Equation W-10A or W-10B).1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(8) For each oil well completion or workover and well type combination, annual CO2emissions, in metric tons CO2. 1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(9) For each oil well completion or workover and well type combination, annual CH4emissions, in metric tons CH4. 1Completions andWorkovers withHydraulic Fracturing ofOil Wells§98.236(g)(10) For each oil well completion or workover and well type combination, the total N2O emissions, in metric tons N2O,if the well emissions were vented to a flare.1Completions andWorkovers withoutHydraulic Fracturing§98.236(h)(1)(i) A list of the well ID numbers forwells associated with each sub-basin that had gas well completions withouthydraulic fracturing and without flaring.1Completions andWorkovers withoutHydraulic Fracturing§98.236(h)(2)(i) A list of the well ID numbers forwells associated with each sub-basin that had gas well completions withouthydraulic fracturing and with flaring.1Completions andWorkovers withoutHydraulic Fracturing§98.236(h)(3)(i) A list of the well ID numbers forwells associated with each sub-basin that had gas well workovers withouthydraulic fracturing and without flaring.1Completions andWorkovers withoutHydraulic Fracturing§98.236(h)(4)(i) A list of the well ID numbers forwells associated with each sub-basin that had gas well workovers withouthydraulic fracturing and with flaring.1Blowdown Vent Stacks §98.236(i)(1)(i) If you calculated emissions from blowdown vent stacks by equipment or event type, the total number ofblowdowns in the calendar year for the equipment orevent type (the sum of equation variable “N” fromEquationW-14A or Equation W-14B of this subpart, for all unique physical volumes for the equipment or event type).1 1Blowdown Vent Stacks §98.236(i)(1)(ii) If you calculated emissions from blowdown vent stacks by equipment type, annual CO2emissions for theequipment type, in metric tons CO2, calculated according to § 98.233(i)(2)(iii).1 1Blowdown Vent Stacks §98.236(i)(1)(iii) If you calculated emissions from blowdown vent stacks by equipment type, annual CH4emissions for theequipment type, in metric tons CH4, calculated according to §98.233(i)(2)(iii).1 1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionBlowdown Vent Stacks §98.236(i)(2)(i) If you electto calculate emissions from blowdown vent stacks by using a flow meter according to §98.233(i)(3),annual CO2emissions from all blowdown vent stacks at the facility for which emissions were calculated usingflow meters, in metric tons CO2(the sum of all CO2mass emission values calculated according to § 98.233(i)(3),for all flow meters).1 1Blowdown Vent Stacks §98.236(i)(2)(ii) If you elect to calculate emissions from blowdown vent stacksby using a flow meter according to §98.233(i)(3),annual CH4emissions from all blowdown vent stacks at the facility for which emissions were calculated usingflow meters, in metric tons CH4, (the sum of all CH4mass emission values calculated according to § 98.233(i)(3),for all flow meters).1 1Blowdown Vent Stacks §98.236(i)(3)(i) For each separate transmission pipeline blowdown event, annualCO2emission in metric tons CO2. 1Blowdown Vent Stacks §98.236(i)(3)(ii) For each separate transmission pipeline blowdown event, annualCH4emission in metric tons CH4. 1Blowdown Vent Stacks §98.236(i)(3)(iii) Latitude and longitude location of the blowdown event in decimal degree format. 1Storage Tanks §98.236(j) Whether your facility sends produced oil to atmospheric tanks.1Storage Tanks §98.236(j) If any of the atmospherictanks are observed to have malfunctioning dump valves, indicate that dump valves weremalfunctioning.1Storage Tanks §98.236(j)(1)(i) If using CalculationMethod 1 or 2, the sub-basin ID.1Storage Tanks §98.236(j)(1)(ii) For the onshore petroleum and natural gas production segment only, ifusing Calculation Method 1 or 2, a list ofthe well ID number(s) associated with the tanks that controlled emissions with flares.1Storage Tanks §98.236(j)(1)(iii) For the onshore petroleum and natural gas production industry segmentonly, if using Calculation Method 1 or 2, alist of the well ID number(s) associated with the tanks that did not control emissions with flares.1Storage Tanks §98.236(j)(1)(iv) If using Calculation Method 1 or 2, calculation method used, and nameof the software package used if usingCalculation Method 1.1Storage Tanks §98.236(j)(1)(v) If using CalculationMethod 1 or 2, the total annual gas-liquid separator oil volume that is sent to applicableonshore storage tanks, in barrels.1Storage Tanks §98.236(j)(1)(vi) If using Calculation Method 1 or 2, the average gas-liquid separator temperature, in degrees Fahrenheit. 1Storage Tanks §98.236(j)(1)(vii) If using Calculation Method 1 or 2, the average gas-liquid separatorpressure, in pounds per square inch gauge. 1Storage Tanks §98.236(j)(1)(viii) If using Calculation Method 1 or 2, the average sales oil or stabilized oil API gravity, in degrees. 1Storage Tanks §98.236(j)(1)(ix) If using Calculation Method 1 or 2, the minimum and maximum concentration (mole fraction) of CO2 in flash gasfrom storage tanks.1Storage Tanks §98.236(j)(1)(x) If using CalculationMethod 1 or 2, the minimum and maximum concentration (mole fraction) of CH4in flash gasfrom storage tanks.1Storage Tanks §98.236(j)(1)(xi) If using Calculation Method 1 or 2, the number of wells sending oil togas-liquid separators or directly toatmospheric tanks.1Storage Tanks §98.236(j)(1)(xii) If using Calculation Method 1 or 2, the number of atmospheric tanks.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionStorage Tanks §98.236(j)(1)(xiv)(A) If using Calculation Method 1 or 2, if any emissions from the atmospheric tanks at your facility were controlledwith vapor recovery systems, the number of atmospheric tanks that control emissions with vapor recovery systems.1Storage Tanks §98.236(j)(1)(xiv)(B) If using Calculation Method 1 or 2, if any emissions from the atmospheric tanks at your facility were controlledwith vapor recovery systems, the total CO2mass, in metric tons CO2, that was recovered during the calendar yearusing a vapor recovery system.1Storage Tanks §98.236(j)(1)(xiv)(C) If using Calculation Method 1 or 2, if any emissions from the atmospheric tanks at your facility were controlledwith vapor recovery systems, the total CH4mass, in metric tons CH4, that was recovered during the calendar yearusing a vapor recovery system.1Storage Tanks §98.236(j)(1)(xiv)(D) If using Calculation Method 1 or 2, if any emissions from the atmospheric tanks at your facility were controlledwith vapor recovery systems, annual CO2 emissions,in metric tons CO2, from atmospheric tanks equippedwithvapor recovery systems.1Storage Tanks §98.236(j)(1)(xiv)(E) If using Calculation Method 1 or 2, if any emissions from the atmospheric tanks at your facility were controlledwith vapor recovery systems, annual CH4 emissions,in metric tons CH4, from atmospheric tanks equippedwithvapor recovery systems.1Storage Tanks §98.236(j)(1)(xv)(A) If using Calculation Method 1 or 2, if any atmospheric tanks at your facility vented gas directly to the atmospherewithout using a vapor recovery system or without flaring, number of atmospheric tanks that vented gasdirectly tothe atmosphere without using a vapor recovery system or without flaring.1Storage Tanks §98.236(j)(1)(xv)(B) If using Calculation Method 1 or 2, if any atmospheric tanks at your facility vented gas directly to the atmospherewithout using a vapor recovery system or without flaring, annual CO2 emissions, in metric tons CO2, that resultedfrom venting gas directly to the atmosphere.1Storage Tanks §98.236(j)(1)(xv)(C) If using Calculation Method 1 or 2, if any atmospheric tanks at your facility vented gas directly to the atmospherewithout using a vapor recovery system or without flaring, annual CH4 emissions, in metric tons CH4, that resultedfrom venting gas directly to the atmosphere.1Storage Tanks §98.236(j)(1)(xvi)(A) If using Calculation Method 1 or 2, if you controlled emissions from any atmospheric tanks at your facility withone or more flares, the number of atmospheric tanksthat controlled emissions with flares.1Storage Tanks §98.236(j)(1)(xvi)(B) If using Calculation Method 1 or 2, if you controlled emissions from any atmospheric tanks at your facility withone or more flares, annual CO2 emissions, in metrictons CO2, from atmospheric tanks that controlled emissionswith one or more flares.1Storage Tanks §98.236(j)(1)(xvi)(C) If using Calculation Method 1 or 2, if you controlled emissions from any atmospheric tanks at your facility withone or more flares, annual CH4 emissions, in metrictons CH4, from atmospheric tanks that controlled emissionswith one or more flares.1Storage Tanks §98.236(j)(1)(xvi)(D) If using Calculation Method 1 or 2, if you controlled emissions from any atmospheric tanks at your facility withone or more flares, annual N2O emissions, in metrictons N2O, from atmospheric tanks that controlled emissionswith one or more flares.1Storage Tanks §98.236(j)(2)(i)(A) If using Calculation Method 3, the total annual oil/condensate throughput that is sent to all atmospheric tanks inthe gathering and boosting facility, in barrels.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionStorage Tanks §98.236(j)(2)(i)(B) If using Calculation Method 3, an estimate of the fraction of oil/condensate throughput reported in paragraph(j)(2)(i)(A) sent to atmospheric tanks in the basinthat controlled emissions with flares.1Storage Tanks §98.236(j)(2)(i)(C) If using Calculation Method 3, an estimate of the fraction of oil/condensate throughput reported in paragraph(j)(2)(i)(A) sent to atmospheric tanks in the basinthat controlled emissions with vapor recovery systems.1Storage Tanks §98.236(j)(2)(i)(D) If using Calculation Method 3, the number of atmospheric tanks in the basin. 1Storage Tanks §98.236(j)(2)(ii)(A) For each sub-basin with atmospheric tanks whose emissions were calculated using Calculation Method 3 and thatdid not control emissions with flares, sub-basin ID.1Storage Tanks §98.236(j)(2)(ii)(B) If using Calculation Method 3, the number of atmospheric tanks inthe sub-basin that did not control emissionswith flares, including those that have vapor recovery.1Storage Tanks §98.236(j)(2)(ii)(B) For the onshorepetroleum and natural gas production segment only,if using Calculation Method 3, a list of thewell ID numbers of wells associated with atmospheric tanks in the sub-basin that did not control emissions withflares.1Storage Tanks §98.236(j)(2)(ii)(C) If using Calculation Method 3, annual CO2 emissions, in metric tons CO2, from atmospheric tanks in the subbasin that did not control emissions with flares, calculated using Equation W-15 of this subpart and adjusted forvapor recovery, if applicable.1Storage Tanks §98.236(j)(2)(ii)(D) If using Calculation Method 3, annual CH4 emissions, in metric tons CH4, from atmospheric tanks in the subbasin that vented gas directly to the atmosphere, calculated using Equation W-15 of this subpart and adjusted forvapor recovery, if applicable.1Storage Tanks §98.236(j)(2)(iii)(A) For each sub-basin with atmospheric tanks whose emissions were calculated using Calculation Method 3 and thatcontrolled emissions with flares, sub-basin ID.1Storage Tanks §98.236(j)(2)(iii)(B) If using Calculation Method 3, the number of atmospheric tanks inthe sub-basin that controlled emissions withflares.1Storage Tanks §98.236(j)(2)(iii)(B) For the onshorepetroleum and natural gas production segment only,if using Calculation Method 3, a list of thewell ID numbers of wells associated with atmospheric tanks in the sub-basin that controlled emissionswith flares.1Storage Tanks §98.236(j)(2)(iii)(C) If using Calculation Method 3, annual CO2emissions, in metric tons CO2, from atmospheric tanks that controlledemissions with flares, calculated using Equation W-15 of this subpart.1Storage Tanks §98.236(j)(2)(iii)(D) If using Calculation Method 3, annual CH4emissions, in metric tons CH4, from atmospheric tanks that controlledemissions with flares, calculated using Equation W-15 of this subpart.1Storage Tanks §98.236(j)(2)(iii)(E) If using Calculation Method 3, annual N2O emissions, in metric tons N2O, from atmospheric tanks that controlledemissions with flares.1Storage Tanks §98.236(j)(3)(i) The total number ofgas-liquid separators whose liquid dump valves didnot close properly during the calendaryear1Storage Tanks §98.236(j)(3)(ii) The total time thedump valves on gas-liquid separators did not closeproperly in the calendar year, in hours (“Tn”in Equation W-16).1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionStorage Tanks §98.236(j)(3)(iii) Annual CO2emissions, in metric tons CO2, that resulted from dump valves on gas-liquid separators not closingproperly during the calendar year, calculated usingEquation W-16 of this subpart.1Storage Tanks §98.236(j)(3)(iv) Annual CH4emissions, in metric tons CH4, that resulted from the dump valves on gas-liquidseparators not closingproperly during the calendar year, calculated usingEquation W-16 of this subpart.1Well Testing Ventingand Flaring§98.236(l)(1)(ii) If you used Equation W-17A to calculate annual volumetric natural gas emissions at actual conditions from oilwells and the emissions are not vented to a flare,well ID numbers for the wells tested in the calendar year.1Well Testing Ventingand Flaring§98.236(l)(2)(ii) If you used Equation W-17A to calculate annual volumetric natural gas emissions at actual conditions from oilwells and the emissions are vented to a flare, wellID numbers for the wells tested in the calendar year.1Well Testing Ventingand Flaring§98.236(l)(3)(ii) If you used Equation W-17B to calculate annual volumetric natural gas emissions at actual conditions from gaswells and the emissions were not vented to a flare,well ID numbers for the wells tested in the calendar year.1Well Testing Ventingand Flaring§98.236(l)(4)(ii) If you used Equation W-17B to calculate annual volumetric natural gas emissions at actual conditions from gaswells and the emissions were vented to a flare, well ID numbers for the wells tested in the calendar year.1Associated Natural GasVenting and Flaring§98.236(m)(1) A list of well ID numbers for wells in each sub-basin for which associated gas was vented or flared. 1Associated Natural GasVenting and Flaring§98.236(m)(7)(i) A list of well ID numbers for wells for which associated gas was vented directly to the atmosphere without flaring. 1Associated Natural GasVenting and Flaring§98.236(m)(8)(i) A list of well ID numbers for wells for which associated gas was flared.1Flare Stacks §98.236(n)(1) Unique name or ID for the flare stack.1Flare Stacks §98.236(n)(2) Indicate whether the flare stack has a continuous flow measurement device.1Flare Stacks §98.236(n)(3) Indicate whether the flare stack has a continuous gas composition analyzeron feed gas to the flare. 1Flare Stacks §98.236(n)(4) Volume of gas sent to the flare, in standard cubic feet (“Vs” in Equations W-19 and W-20 of this subpart). 1Flare Stacks §98.236(n)(5) Fraction of the feed gas sent to an un-lit flare (“Zu” in Equation W-19 of this subpart). 1Flare Stacks §98.236(n)(6) Flare combustion efficiency, expressed as the fraction of gas combusted bya burning flare. 1Flare Stacks §98.236(n)(7) Mole fraction of CH4in the feed gas to the flare (“XCH4” in Equation W-19 of this subpart). 1Flare Stacks §98.236(n)(8) Mole fraction of CO2in the feed gas to the flare (“XCO2” in Equation W-20 of this subpart). 1Flare Stacks §98.236(n)(9) Annual CO2emissions, in metric tons CO2(refer to Equation W-20 of this subpart). 1Flare Stacks §98.236(n)(10) Annual CH4emissions, in metric tons CH4(refer to Equation W-19 of this subpart), unless aCEMS was used tomeasure emissions.1Flare Stacks §98.236(n)(11) Annual N2O emissions, in metric tons N2O (refer to Equation W-40 of this subpart), unlessa CEMS was used tomeasure emissions.1Flare Stacks §98.236(n)(12) Whether a CEMS was used to measure emissions from the flare.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionFlare Stacks §98.236(n)(13) For the onshore petroleum and natural gas production industry segment only, the well ID number(s) associatedwith each unique name or ID for the flare stack.1Centrifugal Compressors §98.236(o)(5)(i) Number ofcentrifugal compressors that have wet seal oil degassing vents.1Centrifugal Compressors §98.236(o)(5)(ii) For the onshore petroleum and natural gas production segmentonly, a list of the well ID numbers for the wellsatwhich the centrifugal compressors that have wet seal oil degassing vents are located.1Centrifugal Compressors §98.236(o)(5)(iii) Annual CO2emissions, in metric tons CO2, from centrifugal compressors with wet seal oil degassing vents 1Centrifugal Compressors §98.236(o)(5)(iv) Annual CH4emissions, in metric tons CH4, from centrifugal compressors with wet seal oil degassing vents. 1ReciprocatingCompressors§98.236(p)(5)(i) Number of reciprocating compressors.1ReciprocatingCompressors§98.236(p)(5)(ii) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers for the wells atwhich reciprocating compressors are located.1ReciprocatingCompressors§98.236(p)(5)(iii) Annual CO2emissions, in metric tons CO2, from reciprocating compressors.1ReciprocatingCompressors§98.236(p)(5)(iv) Annual CH4emissions, in metric tons CH4, from reciprocating compressors.1Equipment Leaks byPopulation Counts§98.236(r)(1)(i)Component type, service type, and geographic location of the emission source type.1Equipment Leaks byPopulation Counts§98.236(r)(1)(i) For the onshore petroleum and natural gas production segment only, a list of well IDnumbers for the associatedwells.1Equipment Leaks byPopulation Counts§98.236(r)(1)(ii) Total number of the emission source type at the facility (“Counte” in Equation W-32A of this subpart). 1Equipment Leaks byPopulation Counts§98.236(r)(1)(iii) Average estimated time that theemission source type was operational in the calendar year, in hours (“Te” inEquation W-32A of this subpart).1Equipment Leaks byPopulation Counts§98.236(r)(1)(iv) Annual CO2emissions, in metric tons CO2, for the component type, service type, and geographic location. 1Equipment Leaks byPopulation Counts§98.236(r)(1)(v) Annual CH4emissions, in metric tons CH4, for the component type, service type, and geographic location. 1Equipment Leaks byPopulation Counts§98.236(r)(3)(i) Calculation method used for equipment leaks.1Equipment Leaks byPopulation Counts§98.236(r)(3)(ii)(A) An indication of whether the facility contains the major equipment type in TableW-1B. 1Equipment Leaks byPopulation Counts§98.236(r)(3)(ii)(B) For each major equipment typein natural gas gathering and boosting, and geographic location combination inTable W-1B, if the facility does contain the equipment type, the count of the major equipment type.1EOR Injection Pumps §98.236(w)(2) The well ID number(s) associated with each EOR injection pump.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionEOR HydrocarbonLiquids§98.236(x)(2) Well ID numbers associated with the EOR operations in each sub-basin.1Combustion §98.236(z)(1)(i) For external fuel combustion units with a rated heat capacity less than orequal to 5 million Btu per hour or internalfuel combustion units that are not compressor-drivers, with a rated heat capacity less than or equal to 1 million Btuper hour (or the equivalent of 130 horsepower), thetype of combustion unit.1Combustion §98.236(z)(1)(ii) For each combustion unit type listed in §98.236(z)(1), the total number of combustion units. 1Combustion §98.236(z)(1)(iii) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers associated witheach combustion unit type listed in §98.236(z)(1).1Combustion §98.236(z)(2)(i) For external fuel combustion units with a rated heat capacity greater than5 mmBtu/hr; internal fuel combustionunits that are not compressor-drivers, with a ratedheat capacity greater than 1 million Btu per hour(or theequivalent of 130 horsepower); or internal fuel combustion units of any heat capacity that are compressor-drivers,the type of combustion unit.1Combustion §98.236(z)(2)(ii) A list of the well IDnumbers associated with the combustion units (for the onshore petroleum and natural gasproduction industry segment only).1Combustion §98.236(z)(2)(iii) For each combustion unit type listed in §98.236(z)(2), the type of fuelcombusted. 1Combustion §98.236(z)(2)(iv) If your facility contains: external fuel combustion units with a rated heat capacity greater than 5 mmBtu/hr;internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than 1 million Btuper hour (or the equivalent of 130 horsepower); orinternal fuel combustion units of any heat capacitythat arecompressor-drivers, report for each combustion unittype and fuel type combination, the quantity of fuelcombusted in the calendar year, in thousand standard cubic feet, gallons, or tons.1Combustion §98.236(z)(2)(v) For each combustion unit type listed in §98.236(z)(2), annual CO2emissions, in metric tons CO2, calculatedaccording to §98.233(z)(1) and (z)(2).1Combustion §98.236(z)(2)(vi) For each combustion unit type listed in §98.236(z)(2), annual CH4emissions, in metric tons CH4, calculatedaccording to §98.233(z)(1) and (z)(2).1Combustion §98.236(z)(2)(vii) For each combustion unit type listed in §98.236(z)(2), annual N2O emissions, in metric tons N2O, calculatedaccording to §98.233(z)(1) and (z)(2).1General §98.236(aa)(1)(ii)(D) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers for producingwells at the end of the calendar year.1General §98.236(aa)(1)(ii)(E) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers for wellsacquired during the calendar year.1General §98.236(aa)(1)(ii)(F) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers for wellsdivested during the calendar year.1General §98.236(aa)(1)(ii)(G) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers for wellscompleted during the calendar year.1Emission SourceCitation ReferenceProposed Rule Text Natural Gas Transmission Pipeline Onshore Natural Gas Gathering and Boosting Onshore Petroleum and Natural Gas ProductionGeneral §98.236(aa)(1)(ii)(H) For the onshore petroleum and natural gas production segment only, a list of the well ID numbers for wells takenout of production during the calendar year.1General §98.236(aa)(10)(i) The quantity of producedgas throughput in the calendar year, in thousand standard cubic feet. 1General §98.236(aa)(10)(ii) The quantity of produced gas consumed by the facility in the calendar year, in thousand standard cubic feet. 1General §98.236(aa)(10)(iii) The quantity of produced condensate throughput in the calendar year, in barrels. 1General §98.236(aa)(10)(iv) The quantity of produced oil throughput in the calendar year, in barrels.1General §98.236(aa)(10)(v) The quantity of gas flared, vented and/or unaccounted for in the calendar year, in thousand standard cubic feet. 1Natural gas transmissionpipelines§98.236(aa)(11)(i) The quantity of natural gas received at all custody transfer stations in the calendar year, in thousand standard cubicfeet. This value may include meter corrections, butonly for the calendar year covered by the annual report.1Natural gas transmissionpipelines§98.236(aa)(11)(ii) The quantity of natural gas withdrawn from in-system storage in the calendar year,in thousand standard cubic feet. 1Natural gas transmissionpipelines§98.236(aa)(11)(iii) The quantity of natural gas added to in-system storage in the calendar year, in thousand standard cubic feet. 1Natural gas transmissionpipelines§98.236(aa)(11)(iv) The quantity of natural gas transferred to third parties such as LDCs or other transmission pipelines, in thousandstandard cubic feet.1Natural gas transmissionpipelines§98.236(aa)(11)(v) The quantity of natural gas consumed by the transmission pipeline facility for operational purposes, in thousandstandard cubic feet.1Natural gas transmissionpipelines§98.236(aa)(11)(vi) The miles of transmission pipeline in the facility.1