Appendix A

List of Data Elements

Petroleum and Natural Gas Systems (Subpart W)
Table A

-1. New Data Elements

Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Natural Gas Pneumatic 

Device Venting

98.236(b) (b) You must indicate whether the facility contains the following types of 

equipment: continuous high bleed natural gas pneumatic devices, continuous 

low bleed natural gas pneumatic devices, and intermittent bleed natural gas 

pneumatic devices. If the facility contains any continuous high bleed natural 

gas pneumatic devices, continuous low bleed natural gas pneumatic devices, 

or intermittent bleed natural gas pneumatic devices, you must report the

information specified in paragraphs (b)(1) through (b)(4) of this section.

111

Natural Gas Pneumatic 

Device Venting

98.236(b)(1)(ii)(C) (C) Whether the calendar year is the first calendar year of reporting or the 

second calendar year of reporting.

111

Natural Gas Pneumatic 

Device Venting

98.236(b)(2) (2) For each type of pneumatic device, the estimated average number of 

hours in the calendar year that the natural gas pneumatic devices reported in 

paragraph (b)(1)(i) of this section were operating in the calendar year (“Tt” 

in Equation W-1 of this subpart).

111

Natural Gas Pneumatic 

Pump Venting

98.236(c) (c) You must indicate whether the facility has any natural gas driven 

pneumatic pumps. If the facility contains any natural gas driven pneumatic 

pumps, then you must report the information specified in paragraphs (c)(1) 

through (c)(4) of this section.

1

Natural Gas Pneumatic 

Pump Venting

98.236(c)(2) (2) Average estimated number of hours in the calendar year the pumps were 

operational (“T” in Equation W-2 of this subpart).

1

Acid Gas Removal 98.236(d) (d) You must indicate whether your facility has any acid gas removal units 

that vent directly to the atmosphere, to a flare or engine, or to a sulfur 

recovery plant. If the facility contains any acid gas removal units that vent 

directly to the atmosphere, to a flare or engine, or to a sulfur recovery plant, 

then you must report the information specified in paragraphs (d)(1) and 

(d)(2) of this section.

11

Acid Gas Removal 98.236(d)(1)(iv) (iv) Whether any CO2 emissions from the acid gas removal unit are 

recovered and transferred outside the facility, according to §98.233(d)(11).

11

Acid Gas Removal 98.236(d)(1)(vi) (vi) Sub-basin ID that best represents the wells supplying gas to the unit (for 

the onshore petroleum and natural gas production industry segments only).

11

Acid Gas Removal 98.236(d)(2)(i)(B) (B) Annual volume of gas vented from the acid gas removal unit, in cubic 

feet.

11

Acid Gas Removal 98.236(d)(2)(ii) and

(d)(2)(ii)(A)

(ii) If you used Calculation Method 3 according to §98.233(d) to calculate 

CO2 emissions from the acid gas removal unit, then you must report the 

information specified in paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) of this 

section.

(A) Which equation was used: Equation W-4A or W-4B.

11

Acid Gas Removal 98.236(d)(2)(iii) and

(d)(2)(iii)(A)

(iii) If you used Calculation Method 4 according to §98.233(d) to calculate 

CO2 emissions from the acid gas removal unit, then you must report the 

information specified in paragraphs (d)(2)(iii)(A) through (d)(2)(iii)(L) of 

this section, as applicable to the simulation software package used.

(A) The name of the simulation software package used.

11

Acid Gas Removal 98.236(d)(2)(iii)(B) (B) Natural gas feed temperature, in degrees Fahrenheit.

11

Acid Gas Removal 98.236(d)(2)(iii)(C) (C) Natural gas feed pressure, in pounds per square inch.

11

A-2
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Acid Gas Removal 98.236(d)(2)(iii)(E) (E) Acid gas content of the feed natural gas, in mole percent. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(F) (F) Acid gas content of the outlet natural gas, in mole percent. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(G) (G) Unit operating hours, excluding downtime for maintenance or standby, in 

hours per year. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(H) (H) Exit temperature of the natural gas, in degrees Fahrenheit. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(I) (I) Solvent pressure, in pounds per square inch. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(J) (J) Solvent temperature, in degrees Fahrenheit. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(K) (K) Solvent circulation rate, in gallons per minute. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(L) (L) Solvent weight, in pounds per gallon. 1 1

Dehydrators 98.236(e) (e) You must indicate whether the facility contains any of the following 

equipment: glycol dehydrators with an annual average daily natural gas 

throughput greater than or equal to 0.4 million standard cubic feet per day, 

glycol dehydrators with an annual average daily natural gas throughput less 

than 0.4 million standard cubic feet per day, and dehydrators that use 

desiccant. If the facility contains any of the equipment listed in this 

paragraph (e), then you must report the applicable information in paragraphs 

(e)(1) through (e)(3).

1 1

Dehydrators 98.236(e)(1)(iii) (iii) Dehydrator feed natural gas water content, in pounds per million 

standard cubic feet. 1 1

Dehydrators 98.236(e)(1)(iv) (iv) Dehydrator outlet natural gas water content, in pounds per million 

standard cubic feet. 1 1

Dehydrators 98.236(e)(1)(vi) (vi) Dehydrator absorbent circulation rate, in gallons per minute. 1 1

Dehydrators 98.236(e)(1)(xvii) (xvii) Whether any dehydrator emissions are vented to the atmosphere 

without being routed to a flare or regenerator firebox/fire tubes. 1 1

Dehydrators 98.236(e)(1)(xviii) (xviii) Sub-basin ID that best represents the wells supplying gas to the 

dehydrator (for the onshore petroleum and natural gas production industry 

segments only).

1 1

Dehydrators 98.236(e)(2)(ii) (ii) ... If any dehydrator emissions were vented to a vapor recovery device, 

then you must report the total number of dehydrators at the facility that 

vented to a vapor recovery device.

1 1

Dehydrators 98.236(e)(2)(iii) (iii) ... If any dehydrator emissions were vented to a control device(s) other 

than a vapor recovery device or a flare or regenerator firebox/fire tubes, then 

you must specify the type of control device(s) and the total number of 

dehydrators at the facility that were vented to each type of control device.

2 2

Dehydrators 98.236(e)(2)(iv) (iv) Whether any dehydrator emissions were vented to a flare or regenerator 

firebox/fire tubes. ... 1 1

Dehydrators 98.236(e)(2)(iv) and

(e)(2)(iv)(A)

(iv) ... If any dehydrator emissions were vented to a flare or regenerator 

firebox/fire tubes, then you must report the information specified in 

paragraphs (e)(2)(iv)(A) through (e)(2)(iv)(D) of this section.

(A) The total number of dehydrators venting to a flare or regenerator 

firebox/fire tubes.

1 1

A-3
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Dehydrators 98.236(e)(3) and

(e)(3)(i)

(3) For dehydrators that use desiccant (according to §98.233(e)(3)), you must 

report the information specified in paragraphs (e)(3)(i) through (e)(3)(iii) of 

this section for the entire facility.

(i) The same information specified in paragraphs (e)(2)(i) through (e)(2)(iv) 

of this section for glycol dehydrators, and report the information under this 

paragraph for dehydrators that use desiccant (whether any dehydrator 

emissions were vented to a vapor recovery device).

11

Dehydrators 98.236(e)(3) and

(e)(3)(i)

(3) For dehydrators that use desiccant (according to §98.233(e)(3)), you must 

report the information specified in paragraphs (e)(3)(i) through (e)(3)(iii) of 

this section for the entire facility.

(i) The same information specified in paragraphs (e)(2)(i) through (e)(2)(iv) 

of this section for glycol dehydrators, and report the information under this 

paragraph for dehydrators that use desiccant. (the total number of

dehydrators vented to a vapor recovery device)

22

Dehydrators 98.236(e)(3) and

(e)(3)(i)

(3) For dehydrators that use desiccant (according to §98.233(e)(3)), you must 

report the information specified in paragraphs (e)(3)(i) through (e)(3)(iii) of 

this section for the entire facility.

(i) The same information specified in paragraphs (e)(2)(i) through (e)(2)(iv) 

of this section for glycol dehydrators, and report the information under this 

paragraph for dehydrators that use desiccant. (whether any dehydrator 

emissions were vented to a control device other than a vapor recovery device 

or a flare or regenerator firebox/fire tubes, and the control device type.)

22

Dehydrators 98.236(e)(3) and

(e)(3)(i)

(3) For dehydrators that use desiccant (according to §98.233(e)(3)), you must 

report the information specified in paragraphs (e)(3)(i) through (e)(3)(iii) of 

this section for the entire facility.

(i) The same information specified in paragraphs (e)(2)(i) through (e)(2)(iv) 

of this section for glycol dehydrators, and report the information under this 

paragraph for dehydrators that use desiccant. (the number of dehydrators 

vented to a control device other than a vapor recovery device or a flare or 

regenerator firebox/fire tubes)

11

Dehydrators 98.236(e)(3) and

(e)(3)(i)

(3) For dehydrators that use desiccant (according to §98.233(e)(3)), you must 

report the information specified in paragraphs (e)(3)(i) through (e)(3)(iii) of 

this section for the entire facility.

(i) The same information specified in paragraphs (e)(2)(i) through (e)(2)(iv) 

of this section for glycol dehydrators, and report the information under this 

paragraph for dehydrators that use desiccant. (whether any glycol 

dehydrator emissions are vented to a flare or regenerator firebox/fire tubes.)

11

Dehydrators 98.236(e)(3) and

(e)(3)(i)

(3) For dehydrators that use desiccant (according to §98.233(e)(3)), you must 

report the information specified in paragraphs (e)(3)(i) through (e)(3)(iii) of 

this section for the entire facility.

(i) The same information specified in paragraphs (e)(2)(i) through (e)(2)(iv) 

of this section for glycol dehydrators, and report the information under this 

paragraph for dehydrators that use desiccant. (the total number of 

dehydrators venting to a flare or regenerator firebox/fire tubes.)

11

Well Venting for Liquids 

Unloading

98.236(f) (f) You must indicate whether well venting for liquids unloading occurs at 

the facility. ...

1

Well Venting for Liquids 

Unloading

98.236(f) (f) ... Indicate which methods (as specified in §98.233(f)) were used to 

calculate emissions....

1

A-4
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Well Venting for Liquids 

Unloading

98.236(f), (f)(1), and

(f)(1)(i)

(f) ... If the facility performs well venting for liquids unloading and uses

Calculation Method 1, then you must report the information specified in 

paragraph (f)(1) of this section. ...

(1) For each sub-basin and well tubing diameter and pressure group for 

which you used Calculation Method 1 to calculate natural gas emissions from 

well venting for liquids unloading, report the information specified in 

paragraphs (f)(1)(i) through (f)(1)(xii) of this section. Report information 

separately for wells with plunger lifts and wells without plunger lifts.

(i) Sub-basin ID.

1

Well Venting for Liquids 

Unloading

98.236(f)(1)(ii) (ii) Well tubing diameter and pressure group ID. 1

Well Venting for Liquids 

Unloading

98.236(f)(1)(v) (v) Percentage of wells for which the monitoring period used to determine 

the cumulative amount of time venting was not the full calendar year. 1

Well Venting for Liquids 

Unloading

98.236(f)(1)(vi) (vi) Cumulative amount of time wells were vented (sum of “Tp” from 

Equation W-7A or W-7B of this subpart), in hours. 1

Well Venting for Liquids 

Unloading

98.236(f)(1)(viii) (viii) Annual natural gas emissions, in standard cubic feet, from well venting 

for liquids unloading, calculated according to §98.233(f)(1). 1

Well Venting for Liquids 

Unloading

98.236(f)(1)(xi) and

(f)(1)(xi)(A)

(xi) For each well tubing diameter group and pressure group combination, 

then you must report the information specified in paragraphs (f)(1)(xi)(A) 

through (f)(1)(xi)(E) of this section for each individual well not using a 

plunger lift that was tested during the year.

(A) API number of tested well.

1

Well Venting for Liquids 

Unloading

98.236(f)(1)(xii) and

(f)(1)(xii)(A)

(xii) For each well tubing diameter group and pressure group combination, 

you must report the information specified in paragraphs (f)(1)(xii)(A) 

through (f)(1)(xii)(E) of this section for each individual well using a plunger 

lift that was tested during the year.

(A) The API well number.

1

Well Venting for Liquids 

Unloading

98.236(f), (f)(2), and 

(f)(2)(i)

(f) ... If the facility performs liquids unloading and uses Calculation Method 

2 or 3, then you must report the information specified in paragraph (f)(2) of 

this section.

(2) For each sub-basin for which you used Calculation Method 2 or 3 

(according to §93.233(f)) to calculate natural gas emissions from well 

venting for liquids unloading, you must report the information in (f)(2)(i) 

through (f)(2)(x) of this section. Report information separately for each 

calculation method.

(i) Sub-basin ID.

1

Well Venting for Liquids 

Unloading

98.236(f)(2)(ii) (ii) Calculation method.

1

Well Venting for Liquids 

Unloading

98.236(f)(2)(vi) (iii) Annual natural gas emissions, in standard cubic feet, from well venting 

for liquids unloading, calculated according to §98.233(f)(2) or §98.233(f)(3), 

as applicable.

1

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g) (g) You must indicate whether the facility had any gas well completions or 

workovers with hydraulic fracturing during the calendar year. ... 1

A-5
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g) and (g)(1) (g) ... If the facility had gas well completions or workovers with hydraulic 

fracturing during the calendar year, then you must report information 

specified in paragraphs (g)(1) through (g)(10) of this section, for each subbasin and well type combination. Report information separately for 

completions and workovers.

(1) Sub-basin ID.

1

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g)(2) (2) Well type combination.

1

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g)(4) (4) Calculation method used.

1

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g)(6)(i) (6) If you used Equation W-10B to calculate annual volumetric total gas 

emissions for completions that vent gas to the atmosphere, then you must 

report the information specified in paragraphs (g)(6)(i) and (g)(6)(ii) of this 

section.

(i) Vented natural gas volume, in standard cubic feet, for each well in the 

sub-basin (“FVs,p” in Equation W-10B).

1

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g)(6)(ii) (ii) Flow rate at the beginning of the period of time when sufficient quantities 

of gas are present to enable separation, in standard cubic feet per hour, for 

each well in the sub-basin (“FRp,i” in Equation W-10A).

1

Completions and 

Workovers with Hydraulic 

Fracturing

98.236(g)(7) (7) Annual gas emissions, in standard cubic feet (“Es,n” in Equation W-10A 

or W-10B). 1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h) (h) You must indicate whether the facility had any gas well completions 

without hydraulic fracturing or any gas well workovers without hydraulic

fracturing, and if the activities occurred with or without flaring. ... 2

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h), (h)(1), and 

(h)(1)(i)

(h) ... If the facility had gas well completions or workovers without 

hydraulic fracturing, then you must report the information specified in 

paragraphs (h)(1) through (h)(4) of this section, as applicable.

(1) For each sub-basin with gas well completions without hydraulic 

fracturing and without flaring, report the information specified in paragraphs 

(h)(1)(i) through (h)(1)(vi) of this section.

(i) Sub-basin ID.

1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(1)(iv) (iv) Average daily gas production rate for all completions without hydraulic 

fracturing in the sub- basin without flaring, in standard cubic feet per hour 

(average of all “Vp” used in Equation W- 13B). You may delay reporting of 

this data element if you indicate in the annual report that wildcat wells and/or 

delineation wells are the only wells that can be used for the measurement. If 

you elect to delay reporting of this data element, you must report by the date 

specified in §98.236(cc) the measured average daily gas production rate for 

all wells during completions and the API Well Number(s) for the wells 

included in the measurement.

1

A-6
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(2) and

(h)(2)(i)

(2) For each sub-basin with gas well completions without hydraulic 

fracturing and with flaring, report the information specified in paragraphs 

(h)(2)(i) through (h)(2)(vii) of this section.

(i) Sub-basin ID.

1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(2)(iii) (iii) Total number of hours that gas vented to a flare during venting for all 

completions in the sub-basin category (the sum of all “Tp” for completions 

that vented to a flare from Equation W-13B).

1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(2)(iv) (iv) Average daily gas production rate for all completions without hydraulic 

fracturing in the sub- basin with flaring, in standard cubic feet per hour (the 

average of all “Vp” from Equation W- 13B). You may delay reporting of this 

data element if you indicate in the annual report that wildcat wells and/or 

delineation wells are the only wells that can be used for the measurement. If 

you elect to delay reporting of this data element, you must report by the date 

specified in §98.236(cc) the measured average daily gas production rate for 

all wells during completions and the API Well Number(s) for the wells 

included in the measurement.

1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(3) and

(h)(3)(i)

(3) For each sub-basin with gas well workovers without hydraulic fracturing 

and without flaring, report the information specified in paragraphs (h)(3)(i) 

through (h)(3)(iv) of this section.

(i) Sub-basin ID.

1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(4) and

(h)(4)(i)

(4) For each sub-basin with gas well workovers without hydraulic fracturing 

and with flaring, report the information specified in paragraphs (h)(4)(i) 

through (h)(4)(iv) of this section.

(i) Sub-basin ID.

1

Blowdown Vent Stacks 98.236(i) (i) You must indicate whether your facility has blowdown vent stacks. ...

111

Blowdown Vent Stacks 98.236(i) (i) ... If the facility has blowdown vent stacks, then you must report whether 

emissions were calculated by equipment or event type or by using flow 

meters, or a combination of both. ...

111

Blowdown Vent Stacks 98.236(i) and (i)(1) (i)... If you calculated emissions by equipment or event type, then you must 

report the information specified in paragraph (i)(1) of this section. ...

(1) ... you must report the equipment or event types...

111

Blowdown Vent Stacks 98.236(i)(1) and 

§98.236(i)(1)(i)

(1) If you calculated emissions from blowdown vent stacks by the seven 

categories listed in §98.233(i)(2), then you must report... the information 

specified in paragraphs (i)(1)(i) through (i)(1)(iii) of this section for each 

equipment or event type. If a blowdown event resulted in emissions from 

multiple equipment or event types and the emissions cannot be apportioned 

to the different equipment or event types, then you may report the 

information in paragraphs (i)(1)(i) through (i)(1)(iii) of this section for the 

equipment or event type that represented the largest portion of the emissions 

for the blowdown event.

(i) Total number of blowdowns in the calendar year for the equipment or 

event type (the sum of equation variable “N” from Equation W-14A or 

Equation W-14B of this subpart, for all unique physical volumes for the 

equipment or event type).

111

Blowdown Vent Stacks 98.236(i)(1)(ii) (ii) Annual CO2 emissions for the equipment or event type, in metric tons 

CO2, as calculated according to §98.233(i)(2)(iii).

111

A-7
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Blowdown Vent Stacks 98.236(i)(1)(iii) (iii) Annual CH4 emissions for the equipment or event type, in metric tons 

CH4, as calculated according to §98.233(i)(2)(iii).

111

Blowdown Vent Stacks 98.236(i)(2) and

(i)(2)(i)

(2) If you elect to calculate emissions from blowdown vent stacks by using a 

flow meter according to §98.233(i)(3), then you must report the information 

specified in paragraphs (i)(2)(i) and (i)(2)(ii) of this section for the facility.

(i) Annual CO2 emissions from all blowdown vent stacks at the facility, in 

metric tons CO2 (the sum all CO2 mass emission values calculated according 

to §98.233(i)(3) for all flow meters).

111

Blowdown Vent Stacks 98.236(i)(2)(ii) (ii) Annual CH4 emissions from all blowdown vent stacks at the facility, in 

metric tons CH4, (the sum all CH4 mass emissions values calculated 

according to §98.233(i)(3) for all flow meters).

111

Onshore Production 

Storage Tanks

98.236(j) (j) You must indicate whether the facility sends produced oil to atmospheric 

tanks....

1

Onshore Production 

Storage Tanks

98.236(j) (j) ... If the facility sends produced oil to atmospheric tanks, then you must 

indicate which Calculation Method(s) you used to calculate GHG emissions

and you must report the information specified in paragraphs (j)(1) and (j)(2) 

of this section as applicable. ...

1

Onshore Production 

Storage Tanks

98.236(j) (j) ... If you used Calculation Method 1 or Calculation Method 2, and any 

atmospheric tanks were observed to have malfunctioning dump valves during 

the calendar year, then you must indicate that dump valves were 

malfunctioning and you must report the information specified in paragraph 

(j)(3) of this section. ...

1

Onshore Production 

Storage Tanks

98.236(j)(1) and

(j)(1)(i)

(1) If you used Calculation Method 1 or Calculation Method 2 to calculate 

GHG emissions, then you must report the information specified in 

paragraphs (j)(1)(i) through (j)(1)(xiv) of this section for each sub-basin, and 

by calculation method.

(i) Sub-basin ID.

1

Onshore Production 

Storage Tanks

98.236(j)(1)(ii) (ii) Calculation method used, and name of the software package used if using 

Calculation Method 1.

1

Onshore Production 

Storage Tanks

98.236(j)(2)(ii) and

(j)(2)(ii)(A)

(ii) Report the information specified in paragraphs (j)(2)(ii)(A) through 

(j)(2)(ii)(D) of this section for each sub-basin with atmospheric tanks whose 

emissions were calculated using Calculation Method 3 and that did not 

control emissions with flares.

(A) Sub-basin ID.

1

Onshore Production 

Storage Tanks

98.236(j)(2)(ii)(B) (B) The number of atmospheric tanks in the sub-basin that did not control 

emissions with flares, including those with vapor recovery.

1

Onshore Production 

Storage Tanks

98.236(j)(2)(iii) and

(j)(2)(iii)(A)

(iii) Report the information specified in paragraphs (j)(2)(iii)(A) through 

(j)(2)(iii)(E) of this section for each sub-basin with atmospheric tanks whose 

emissions were calculated using Calculation Method 3 and that controlled 

emissions with flares.

(A) Sub-basin ID.

1

Onshore Production 

Storage Tanks

98.236(j)(2)(iii)(B) (B) The number of atmospheric tanks in the sub-basin that controlled 

emissions with flares.

1

Onshore Production 

Storage Tanks

98.236(j)(3)(ii) (ii) The total time the dump valves on gas-liquid separators did not close 

properly in the calendar year, in hours (“Tn” in Equation W-16 of this 

subpart).

1

A-8
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Transmission Storage 

Tanks

98.236(k) (k) You must indicate whether your facility contains any transmission 

storage tanks. ... 1

Transmission Storage 

Tanks

98.236(k)(1)(ii) (ii) Method used to determine if dump valve leakage occurred.

1

Transmission Storage 

Tanks

98.236(k)(1)(iii) (iii) Indicate whether scrubber dump valve leakage occurred for the 

transmission storage tank vent according to §98.233(k)(2). 1

Transmission Storage 

Tanks

98.236(k)(1)(iv) (iv) Indicate if there is a flare attached to the transmission storage tank vent 

stack. 1

Transmission Storage 

Tanks

98.236(k)(2) and

(k)(2)(i)

(2) If scrubber dump valve leakage occurred for a transmission storage tank 

vent stack, as reported in paragraph (k)(1)(iii) of this section, and the vent 

stack vented directly to the atmosphere during the calendar year, then you 

must report the information specified in paragraphs (k)(2)(i) through 

(k)(2)(v) of this section for each transmission storage vent stack where 

scrubber dump valve leakage occurred.

(i) Method used to measure the leak rate.

1

Transmission Storage 

Tanks

98.236(k)(2)(ii) (ii) Measured leak rate (average leak rate from a continuous flow 

measurement device) in standard cubic feet per hour. 1

Transmission Storage 

Tanks

98.236(k)(2)(iii) (iii) Duration of time that the leak is counted as having occurred, in hours, as 

determined in 98.233(k)(3) (may use best available data if a continuous flow 

measurement device was used).

1

Transmission Storage 

Tanks

98.236(k)(3) and

(k)(3)(i)

(3) If scrubber dump valve leakage occurred for a transmission storage tank 

vent stack, as reported in paragraph (k)(1)(iii) and the vent stack vented to a 

flare during the calendar year, then you must report the information specified 

in paragraphs (k)(3)(i) through (k)(3)(vi).

(i) Method used to measure the leak rate.

1

Transmission Storage 

Tanks

98.236(k)(3)(ii) (ii) Measured leakage rate (average leak rate from a continuous flow 

measurement device), in standard cubic feet per hour. 1

Transmission Storage

Tanks

98.236(k)(3)(iii) (iii) Duration of time that flaring occurred, in hours (may use best available 

data if a continuous flow measurement device was used). 1

Well Testing Venting and 

Flaring

98.236(l) (l) You must indicate whether you performed gas well or oil well testing, and 

if the testing of gas wells or oil wells resulted in vented or flared emissions 

during the calendar year. ...

1

Well Testing Venting and 

Flaring

98.236(l)(1)(iv) (iv) Average flow rate for well(s) tested, in barrels of oil per day. You may 

delay reporting of this data element if you indicate in the annual report that

wildcat wells and/or delineation wells are the only wells that can be used for 

the measurement. If you elect to delay reporting of this data element, you 

must report by the date specified in §98.236(cc) the measured average annual 

production rate for well(s) tested and the API Well Number(s) for the wells

included in the measurement.

1

A-9
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Well Testing Venting and 

Flaring

98.236(l)(2)(iv) (iv) Average flow rate for well(s) tested, in barrels of oil per day. You may 

delay reporting of this data element if you indicate in the annual report that 

wildcat wells and/or delineation wells are the only wells that are tested. If 

you elect to delay reporting of this data element, you must report by the date 

specified in §98.236(cc) the measured average annual production rate for 

well(s) tested and the API Well Number(s) for the wells included in the 

measurement.

1

Well Testing Venting and 

Flaring

98.236(l)(3)(iii) (iii) Average annual production rate for well(s) tested in actual cubic feet per 

day. You may delay reporting of this data element if you indicate in the 

annual report that wildcat wells and/or delineation wells are the only wells 

that are tested. If you elect to delay reporting of this data element, you must 

report by the date specified in §98.236(cc) the measured average annual 

production rate for well(s) tested and the API Well Number(s) for the wells 

included in the measurement.

1

Well Testing Venting and 

Flaring

98.236(l)(4)(iii) (iii) Average annual production rate for well(s) tested, in actual cubic feet per 

day. You may delay reporting of this data element if you indicate in the 

annual report that wildcat wells and/or delineation wells are the only wells 

that are tested. If you elect to delay reporting of this data element, you must 

report by the date specified in §98.236(cc) the measured average annual 

production rate for well(s) tested and the API Well Number(s) for the wells 

included in the measurement.

1

Associated Natural Gas 

Venting and Flaring

98.236(m) (m) You must indicate whether any associated gas was vented or flared 

during the calendar year. ... 1

Associated Natural Gas 

Venting and Flaring

98.236(m) and (m)(1) (m) ... If associated gas was vented or flared during the calendar year, then 

you must report the information specified in paragraphs (m)(1) through 

(m)(8) of this section for each sub-basin.

(1) Sub-basin ID.

1

Associated Natural Gas 

Venting and Flaring

98.236(m)(2) (2) Indicate whether any associated gas was vented directly to the 

atmosphere without flaring. 1

Associated Natural Gas 

Venting and Flaring

98.236(m)(3) (3) Indicate whether any associated gas was flared. 1

Associated Natural Gas 

Venting and Flaring

98.236(m)(5) (5) Volume of oil produced, in barrels, in the calendar year during the time 

periods in which associated gas was vented or flared (the sum of “Vp,q” used 

in Equation W-18 of paragraph (j) of this section). You may delay reporting 

of this data element if you indicate in the annual report that wildcat wells 

and/or delineation wells are the only wells from which associated gas was 

vented or flared. If you elect to delay reporting of this data element, you 

must report by the date specified in §98.236(cc) the volume of oil produced 

for well(s) with associated gas venting and flaring and the API Well 

Number(s) for the wells included in the measurement.

1

A-10
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Associated Natural Gas 

Venting and Flaring

98.236(m)(6) (6) Total volume of associated gas sent to sales, in standard cubic feet, in the 

calendar year during time periods in which associated gas was vented or 

flared (the sum of “SG” values used in Equation W-18 of §98.233(m)). You 

may delay reporting of this data element if you indicate in the annual report 

that wildcat wells and/or delineation wells are the only wells from which 

associated gas was vented or flared. If you elect to delay reporting of this 

data element, you must report by the date specified in §98.236(cc) the 

measured total volume of associated gas sent to sales for well(s) with 

associated gas venting and flaring and the API Well Number(s) for the wells 

included in the measurement.

1

Flare Stack Emissions 98.236(n) (n) You must indicate if your facility contains any flare stacks. ... 1 1 1 1 1 1

Flare Stack Emissions 98.236(n)(7) (7) Mole fraction of CH4 in the feed gas to the flare (“XCH4” in Equation 

W-19 of this subpart). 1 1 1 1 1 1

Flare Stack Emissions 98.236(n)(8) (8) Mole fraction of CO2 in the feed gas to the flare (“XCO2” in Equation 

W-20 of this subpart). 1 1 1 1 1 1

Centrifugal Compressors 98.236(o) (o) You must indicate whether your facility has centrifugal compressors. ... 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1) and

(o)(1)(i)

(1) Report the information specified in paragraphs (o)(1)(i) through 

(o)(1)(xiv) of this section for each centrifugal compressor located at your

facility.

(i) Unique name or ID for the centrifugal compressor.

1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(iv) (iv) Indicate whether the compressor was measured in operating-mode. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(v) (v) Indicate whether the compressor was measured in not-operatingdepressurized-mode. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(vi) (vi) Indicate which, if any, compressor sources are part of a manifolded 

group of compressor sources. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(vii) (vii) Indicate which, if any, compressor sources are routed to a flare. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(viii) (viii) Indicate which, if any, compressor sources have vapor recovery. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(ix) (ix) Indicate which, if any, compressor source emissions are captured for fuel 

use or are routed to a thermal oxidizer. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(x) (x) Indicate whether the compressor has blind flanges installed and 

associated dates. 2 2 2 2 2

Centrifugal Compressors 98.236(o)(1)(xi) (xi) Indicate whether the compressor has wet or dry seals. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(xiii) (xiii) Power output of the compressor driver (hp). 1 1 1 1 1

Centrifugal Compressors 98.236(o)(1)(xiv) (xiv) Indicate whether the compressor had a scheduled depressurized 

shutdown during the reporting year. 1 1 1 1 1

Centrifugal Compressors 98.326(o)(2)(i) and

(o)(2)(i)(A)

(i) For each compressor source at each compressor, report the information 

specified in paragraphs (o)(2)(i)(A) through (o)(2)(i)(C) of this section.

(A) Centrifugal compressor name or ID. Use the same ID as in paragraph 

(o)(1)(i) of this section.

1 1 1 1 1

Centrifugal Compressors 98.326(o)(2)(i)(B) (B) Centrifugal compressor source (wet seal, isolation valve, or blowdown 

valve). 1 1 1 1 1

A-11
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Centrifugal Compressors 98.326(o)(2)(i)(C) (C) Unique name or ID for the leak or vent. If the leak or vent is connected a 

manifolded group of compressor sources, use the same leak or vent ID for 

each compressor source in the manifolded group. If multiple compressor 

sources are released through a single vent for which continuous 

measurements are used, use the same leak or vent ID for each compressor 

source released via the measured vent. For a single compressor using as 

found measurements, you must provide a different leak or vent ID for each 

compressor source.

11111

Centrifugal Compressors 98.326(o)(2)(ii) and 

(o)(2)(ii)(A)

(ii) For each leak or vent, report the information specified in paragraphs 

(o)(2)(ii)(A) through (o)(2)(ii)(E) of this section. 

(A) Indicate whether the leak or vent is for a single compressor source or 

manifolded group of compressor sources and whether the emissions from the 

leak or vent are released to the atmosphere, routed to a flare, combustion 

(fuel or thermal oxidizer), or vapor recovery.

11111

Centrifugal Compressors 98.326(o)(2)(ii)(B) (B) Indicate whether an as found measurement(s) as identified in 

§98.233(o)(2) or (o)(4) was conducted on the leak or vent.

11111

Centrifugal Compressors 98.326(o)(2)(ii)(C) (C) Indicate whether continuous measurements as identified in §98.233(o)(3) 

or (o)(5) were conducted on the leak or vent.

11111

Centrifugal Compressors 98.236(o)(2)(ii)(E) (E) If the leak or vent is routed to flare, combustion, or vapor recovery, 

report the percentage of time that the respective device was operational when 

compressor source emissions were routed to the device.

11111

Centrifugal Compressors 98.236(o)(3), (o)(3)(i),

and (o)(3)(i)(A)

(3) If the measurement methods specified in paragraphs §98.233(o)(2) or 

(o)(4) are conducted, report the information specified in paragraph (o)(3)(i) 

of this section. ...

(i) For each as found measurement performed on a leak or vent, report the 

information specified in paragraphs (o)(3)(i)(A) through (o)(3)(i)(E) of this 

section.

(A) Name or ID of leak or vent. Use same leak or vent ID as in paragraph 

(o)(2)(i)(C) of this section.

11111

Centrifugal Compressors 98.236(o)(3)(i)(B) (B) Measurement date.

11111

Centrifugal Compressors 98.236(o)(3)(i)(C) (C) Measurement method. If emissions were not detected when using a 

screening method, report the screening method. If emissions were detected 

using a screening method, report only the method subsequently used to 

measure the volumetric emissions.

11111

Centrifugal Compressors 98.236(o)(3)(i)(D) (D) Measured flow rate, in standard cubic feet per hour.

11111

Centrifugal Compressors 98.236(o)(3)(i)(E) (E) For each compressor attached to the leak or vent, report the compressor 

mode during which the measurement was taken.

11111

Centrifugal Compressors 98.236(o)(3)(i)(F) (F) If the measurement is for a manifolded group of compressor sources, 

indicate whether the measurement location is prior to or after comingling 

with non-compressor emission sources.

11111

Centrifugal Compressors 98.236(o)(3)(ii) and

(o)(3)(ii)(A)

(ii) For each compressor mode-source combination where a reporter emission 

factor as calculated in Equation W-23 was used to calculate emissions in 

Equation W-22, report the information specified in paragraphs (o)(3)(ii)(A) 

through (o)(3)(ii)(D) of this section.

(A) The compressor mode-source combination.

11111

A-12
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Centrifugal Compressors 98.236(o)(3)(ii)(C) (C) The total number of compressors measured in the compressor modesource combination in the current reporting year and the preceding two 

reporting years (“Countm” in Equation W-23).

1 1 1 1 1

Centrifugal Compressors 98.236(o)(3)(ii)(D) (D) Indicate whether the compressor mode-source combination reporter 

emission factor is facility-specific or based on all of the reporter's applicable 

facilities.

1 1 1 1 1

Centrifugal Compressors 98.236(o)(4) and

(o)(4)(i)

(4) If the measurement methods specified in paragraphs §98.233(o)(3) or 

(o)(5) are conducted, report the information specified in paragraphs (o)(4)(i) 

through (o)(4)(iii) of this section for each continuous measurement 

conducted on each leak or vent associated with each compressor source or 

manifolded group of compressor sources.

(i) Name or ID of leak or vent. Use same leak or vent ID as in paragraph 

(o)(2)(i)(C) of this section.

1 1 1 1 1

Centrifugal Compressors 98.236(o)(4)(ii) (ii) Measured volume of flow during the reporting year, in million standard 

cubic feet. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(4)(iii) (iii) Indicate whether the measured volume of flow during the reporting year 

includes compressor blowdown emissions as allowed for in §98.233(o)(3)(ii) 

and (o)(5)(iii).

1 1 1 1 1

Centrifugal Compressors 98.236(o)(4)(iv) (iv) If the measurement is for a manifolded group of compressor sources, 

indicate whether the measurement location is prior to or after comingling 

with non-compressor emission sources.

1 1 1 1 1

Reciprocating Compressors 98.236(p) (p) You must indicate whether your facility has reciprocating compressors.

... 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1) and

(p)(1)(i)

(1) Report the information specified in paragraphs (p)(1)(i) through 

(p)(1)(xiv) of this section for each reciprocating compressor located at your

facility.

(i) Unique name or ID for the reciprocating compressor.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(v) (v) Indicate whether the compressor was measured in operating-mode.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(vi) (vi) Indicate whether the compressor was measured in standby-pressurizedmode. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(vii) (vii) Indicator whether the compressor was measured in not-operatingdepressurized-mode. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(viii) (viii) Indicate which, if any, compressor sources are part of a manifolded 

group of compressor sources. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(ix) (ix) Indicate which, if any, compressor sources are routed to a flare. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(x) (x) Indicate which, if any, compressor sources have vapor recovery. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(xi) (xi) Indicate which, if any, compressor source emissions are captured for fuel 

use or are routed to a thermal oxidizer. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(xii) (xii) Indicate whether the compressor has blind flanges installed and 

associated dates. 2 2 2 2 2

A-13
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Reciprocating Compressors 98.236(p)(1)(xiii) (xiii) Power output of the compressor driver (hp). 1 1 1 1 1

Reciprocating Compressors 98.236(p)(1)(xiv) (xiv) Indicate whether the compressor has a scheduled depressurized 

shutdown during the reporting year. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(i) and

(p)(2)(i)(A)

(i) For each compressor source at each compressor, report the information 

specified in paragraphs (p)(2)(i)(A) through (p)(2)(i)(C) of this section.

(A) Reciprocating compressor name or ID. Use the same ID as in paragraph 

(p)(1)(i) of this section.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(i)(B) (B) Reciprocating compressor source (isolation valve, blowdown valve, or 

rod packing). 1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(i)(C) (C) Unique name or ID for the leak or vent. If the leak or vent is connected to 

a manifolded group of compressor sources, use the same leak or vent ID for 

each compressor source in the manifolded group. If multiple compressor 

sources are released through a single vent for which continuous 

measurements are used, use the same leak or vent ID for each compressor 

source released via the measured vent. For a single compressor using as 

found measurements, you must provide a different leak or vent ID for each 

compressor source.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(ii)(A) (A) Indicate whether the leak or vent is for a single compressor source or 

manifolded group of compressor sources and whether the emissions from the 

leak or vent are released to the atmosphere, routed to a flare, combustion 

(fuel or thermal oxidizer), or vapor recovery.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(ii)(B) (B) Indicate whether an as found measurement(s) as identified in 

§98.233(p)(2) or (p)(4) was conducted on the leak or vent. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(ii)(C) (C) Indicate whether continuous measurements as identified in §98.233(p)(3) 

or (p)(5) were conducted on the leak or vent. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(2)(ii)(E) (E) If the leak or vent is routed to flare, combustion, or vapor recovery, 

report the percentage of time that the respective device was operational when 

the compressor source emissions were routed to the device.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(3), (p)(3)(i),

and (p)(3)(i)(A)

(3) If the measurement methods specified in paragraphs §98.233(p)(2) or 

(p)(4) are conducted, report the information specified in paragraphs (p)(3)(i) 

of this section. If the calculation specified in paragraph §98.233(p)(6)(ii) is 

performed, report the information specified in paragraph (p)(3)(ii) of this 

section.

(i) For each as found measurement performed on a leak or vent, report the 

information specified in paragraphs (p)(3)(i)(A) through (p)(3)(i)(E) of this 

section.

(A) Name or ID of leak or vent. Use the same leak or vent ID as in paragraph 

(p)(2)(i)(C) of this section.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(i)(B) (B) Measurement date. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(i)(C) (C) Measurement method. If emissions were not detected when using a 

screening method, report the screening method. If emissions were detected 

using a screening method, report only the method used to measure the 

volumetric emissions.

1 1 1 1 1

A-14
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Reciprocating Compressors 98.236(p)(3)(i)(D) (D) Measured flow rate, in standard cubic feet per hour. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(i)(E) (E) For each compressor attached to the leak or vent, report the compressor 

mode during which the measurement was taken. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(i)(F) (F) If the measurement is for a manifolded group of compressor sources, 

indicate whether the measurement location is prior to or after comingling 

with non-compressor emissions sources.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(ii) and

(p)(3)(ii)(A)

(ii) For each compressor mode-source combination where a reporter emission 

factor as calculated in Equation W-28 was used to calculate emissions in 

Equation W-27, report the information specified in paragraphs (p)(3)(ii)(A) 

through (p)(3)(ii)(D) of this section.

(A) The compressor mode-source combination.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(ii)(C) (C) The total number of compressors measured in the compressor modesource combination in the current reporting year and the preceding two 

reporting years (“Countm” in Equation W- 28).

1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(ii)(D) (D) Indicate whether the compressor mode-source combination reporter 

emission factor is facility-specific or based on all of the reporter's applicable 

facilities.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(4) and

(p)(4)(i)

(4) If the measurement methods specified in paragraphs §98.233(p)(3) or 

(p)(5) are conducted, report the information specified in paragraphs (p)(4)(i) 

through (p)(4)(iii) of this section for each continuous measurement 

conducted on each leak or vent associated with each compressor source or 

manifolded group of compressor sources.

(i) Name or ID of leak or vent. Use same leak or vent ID as in paragraph 

(p)(2)(i)(C) of this section.

1 1 1 1 1

Reciprocating Compressors 98.236(p)(4)(ii) (ii) Measured volume of flow during the reporting year, in million standard 

cubic feet. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(4)(iii) (iii) Indicate whether the measured volume of flow during the reporting year 

includes compressor blowdown emissions as allowed for in §98.233(p)(3)(ii) 

and (p)(5)(iii).

1 1 1 1 1

Reciprocating Compressors 98.236(p)(4)(iv) (iv) If the measurement is for a manifolded group of compressor sources, 

indicate whether the measurement location is prior to or after comingling 

with non-compressor emission sources.

1 1 1 1 1

Equipment Leaks by Leak 

Detection

98.236(q), (q)(1), and

(q)(1)(i)

(q) If the facility is subject to the requirements of §98.233(q), then you must 

report the information specified in paragraphs (q)(1) and (q)(2) of this 

section. Natural gas distribution facilities with emission sources listed in 

§98.232(i)(1) must also report the information specified in paragraph (q)(3) 

of this section.

(1) You must report the information specified in paragraphs (q)(1)(i) and 

(q)(1)(ii) of this section.

(i) Except as specified in paragraph (q)(1)(ii) of this section, the number of 

complete equipment leak surveys performed during the calendar year.

1 1 1 1 1 1

A-15
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Equipment Leaks by Leak 

Detection

98.236(q)(2) and

(q)(2)(i)

(2) You must indicate whether the facility contains any of the component 

types listed in §98.233(d)(7), (e)(7), (f)(5), (g)(3), (h)(4), or (i)(1), for the 

facility’s industry segment. For each component type that is located at the 

facility, you must report the information specified in paragraphs (q)(2)(i) 

through (q)(2)(v) of this section. If a component type is located at the facility, 

and no leaks were identified from that component, then you must report the 

information in paragraphs (q)(2)(i) through (q)(2)(v) of this section but report 

a zero (“0”) for the information required according to paragraphs (q)(2)(iii), 

(q)(2)(iv), and (q)(2)(v) of this section.

(i) Component type.

111111

Equipment Leaks by Leak 

Detection

98.236(q)(2)(iii) (iii) Average time the surveyed components are assumed to be leaking and 

operational, in hours (average of Tp,z from Equation W-30 of this subpart for 

the component type).

111111

Equipment Leaks by Leak 

Detection

98.236(q)(3)(ii) (ii) Number of meter/regulator runs at above grade transmission-distribution 

transfer stations surveyed in the calendar year (“CountMR,y” from Equation 

W-31 of this subpart, for the current calendar year).

1

Equipment Leaks by Leak 

Detection

98.236(q)(3)(iii) (iii) Average time that meter/regulator runs surveyed in the calendar year 

were operational, in hours (average of “Tw,y” from Equation W-31 of this 

subpart, for the current calendar year).

1

Equipment Leaks by Leak 

Detection

98.236(q)(3)(v) (v) Number of meter/regulator runs at above grade transmission-distribution 

transfer stations surveyed in current leak survey cycle (sum of “CountMR,y”

from Equation W-31 of this subpart, for all calendar years in the current leak 

survey cycle).

1

Equipment Leaks by Leak 

Detection

98.236(q)(3)(vi) (vi) Average time that meter/regulator runs surveyed in the current leak 

survey cycle were operational, in hours (average of “Tw,y” from Equation 

W-31 of this subpart, for all years included in the leak survey cycle).

1

Equipment Leaks by Leak 

Detection

98.236(q)(3)(ix)(A) The total number of meter/regulator runs at above grade transmission-

distribution transfer stations at your facility (“CountMR” in Equation W-32B 

of this subpart).

1

Equipment Leaks by Leak 

Detection

98.236(q)(3)(ix)(B) Average estimated time that each meter/regulator run at above grade 

transmission-distribution transfer stations was operational in the calendar 

year, in hours per meter/regulator run (“Tw,avg” in Equation W-32B of this 

subpart)

1

Equipment Leaks by 

Population Counts

98.236(r) and (r)(1) (r) If your facility is subject to the requirements of §98.233(r), then you must 

report the information specified in paragraphs (r)(1) through (r)(3) of this 

section, as applicable. (1) You must indicate whether the facility contains any 

of the emission source types required to use Equation W-32A of this subpart. 

You must report the information specified in paragraphs (r)(1)(i) through 

(r)(1)(v) of this section separately for each emission source type required to 

use Equation W-32A of this subpart that is located at your facility. Onshore 

petroleum and natural gas production facilities must report the information 

specified in paragraphs (r)(1)(i) through (r)(1)(v) of this section separately by 

component type, service type, and geographic location (i.e., Eastern U.S. or 

Western U.S.).

11111

Equipment Leaks by 

Population Counts

98.236(r)(1)(i) (i) Emission source type. Onshore petroleum and natural gas production 

facilities must report the component type, service type and geographic 

location.

11111

A-16
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Equipment Leaks by 

Population Counts

98.236(r)(1)(iii) (iii) Average estimated time that the emission source type was operation in 

the calendar year, in hours (“Te” in Equation W-32A of this subpart). 1 1 1 1 1

Equipment Leaks by 

Population Counts

98.236(r)(2)(iii) (iii) Total number of meter/regulator runs at above grade metering-regulating 

stations that are not above grade transmission-distribution transfer stations 

(“CountMR” in Equation W-32B of this subpart).

1

Equipment Leaks by 

Population Counts

98.236(r)(2)(iv) (iv) Average estimated time that each meter/regulator run at above grade 

metering-regulating stations that are not above grade transmissiondistribution transfer stations was operational in the calendar year, in hours 

per meter/regulator run (“Tw,avg” in Equation W-32B of this subpart).

1

Equipment Leaks by 

Population Counts

98.236(r)(2)(v)(A) (A) Annual CO2 emissions, in metric tons CO2, from above grade meteringregulating stations that are not above grade transmission-distribution transfer 

stations.

1

Equipment Leaks by 

Population Counts

98.236(r)(2)(v)(B) (B) Annual CH4 emissions, in metric tons CH4, from above grade meteringregulating stations that are not above grade transmission-distribution transfer 

stations.

1

Equipment Leaks by 

Population Counts

98.236(r)(3) and

(r)(3)(i)

(3) Onshore petroleum and natural gas production facilities must also report 

the information specified in paragraphs (r)(3)(i) and (r)(3)(ii) of this section.

(i) Calculation method used.

1

Equipment Leaks by 

Population Counts

98.236(r)(3)(ii) and

(r)(3)(ii)(A)

(ii) Onshore petroleum and natural gas production facilities must report the 

information specified in paragraphs (r)(3)(ii)(A) and (r)(3)(ii)(B) of this 

section, for each major equipment type, production type (i.e., natural gas or 

crude oil), and geographic location combination in Tables W-1B and W-1C 

of this subpart.

(A) An indication of whether the facility contains the major equipment type.

1

EOR Injection Pump 

Blowdown

98.236(w) (w) You must indicate whether CO2 EOR injection was used at your facility 

during the calendar year, and if any EOR injection pump blowdowns 

occurred during the year. If any EOR injection pump blowdowns occurred 

during the calendar year, then you must report the information specified in 

paragraphs (w)(1) through (w)(8) of this section for each EOR injection 

pump system.

2

EOR Injection Pump 

Blowdown

98.236(w)(1) (1) Sub-basin ID.

1

EOR Injection Pump 

Blowdown

98.236(w)(2) (2) EOR injection pump system identifier.

1

EOR Injection Pump 

Blowdown

98.236(w)(7) (7) Mass fraction of CO2 in critical phase EOR injection gas (“GHGCO2” in 

Equation W-37 of this subpart). 1

EOR hydrocarbon liquid 

dissolved CO2

98.236(x) (x) You must indicate whether hydrocarbon liquids were produced through 

EOR operations. ... 1

EOR hydrocarbon liquid 

dissolved CO2

98.236(x) and (x)(1) (x) ... If hydrocarbon liquids were produced through EOR operations, you 

must report the information specified in paragraphs (x)(1) through (x)(4) of 

this section for each sub-basin category with EOR operations.

(1) Sub-basin ID.

1

A-17
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Combustion 98.236(z) (z)If the facility is required by §98.232(c)(22) or (i)(7) to report emissions 

from combustion equipment, then you must indicate whether the facility has 

any combustion units subject to reporting according to paragraphs 

(a)(1)(xvii) or (a)(8)(i) of this section....

11

Combustion 98.236(z) and (z)(1) (z) ... If the facility contains any combustion units subject to reporting 

according to paragraphs (a)(1)(xvii) or (a)(8)(i) of this section, then you must 

report the information specified in paragraphs (z)(1) and (z)(2) of this 

section, as applicable.

(1) Indicate whether the combustion units include: external fuel combustion 

units with a rated heat capacity less than or equal to 5 million Btu per hour; 

or, internal fuel combustion units that are not compressor-drivers, with a 

rated heat capacity less than or equal to 1 mmBtu per hour (or the equivalent 

of 130 horsepower). ...

11

Combustion 98.236(z)(1) and

(z)(1)(i)

(1)... If the facility contains external fuel combustion units with a rated heat 

capacity less than or equal to 5 million Btu per hour or internal fuel 

combustion units that are not compressor-drivers, with a rated heat capacity 

less than or equal to 1 million Btu per hour (or the equivalent of 130 

horsepower), then you must report the information specified in paragraphs 

(z)(1)(i) and (z)(1)(ii) of this section for each unit type.

(i) The type of combustion unit.

11

Combustion 98.236(z)(2) (2) Indicate whether the combustion units include: external fuel combustion 

units with a rated heat capacity greater than 5 million Btu per hour; internal 

fuel combustion units that are not compressor-drivers, with a rated heat 

capacity greater than 1 million Btu per hour (or the equivalent of 130 

horsepower); or, internal fuel combustion units of any heat capacity that are 

compressor-drivers....

11

Combustion 98.236(z)(2)(ii) (ii) The type of fuel combusted.

11

Onshore Petroleum and 

Natural Gas Production

98.236(aa), (aa)(1),

(aa)(1)(i), and

(aa)(1)(i)(A)

(aa) Each facility must report the information specified in paragraphs (aa)(1) 

through (aa)(9) of this section, for each applicable industry segment, by using 

best available data. If a quantity required to be reported is zero, you must 

report zero as the value.

(1) For onshore petroleum and natural gas production, report the data 

specified in paragraphs (aa)(1)(i) and (aa)(1)(ii) of this section.

(i) Report the information specified in paragraphs (aa)(1)(i)(A) through 

(aa)(1)(i)(D) of this section for the basin as a whole.

(A) The quantity of gas produced in the calendar year from wells, in 

thousand standard cubic feet. This includes gas that is routed to a pipeline, 

vented or flared, or used in field operations. This does not include gas 

injected back into reservoirs or shrinkage resulting from lease condensate 

production.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(i)(B) (B) The quantity of gas produced in the calendar year for sales, in thousand 

standard cubic feet.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(i)(C) (C) The quantity of crude oil and condensate produced in the calendar year 

for sales, in barrels.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii) and

(aa)(1)(ii)(A)

(ii) Report the information specified in paragraphs (aa)(1)(ii)(A) through 

(aa)(1)(ii)(M) of this section for each unique sub-basin category.

(A) State.

1

A-18
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(B) (B) County.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(C) (C) Formation type.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(D) (D) The number of producing wells at the end of the calendar year (exclude 

only those wells permanently taken out of production, i.e., plugged and 

abandoned).

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(E) (E) The number of producing wells acquired during the calendar year.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(F) (F) The number of producing wells divested during the calendar year.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(G) (G) The number of wells completed during the calendar year.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(H) (H) The number of wells permanently taken out of production (i.e., plugged 

and abandoned) during the calendar year.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(I) (I) Average mole fraction of CH4 in produced gas.

1

Onshore Petroleum and 

Natural Gas Production

98.236(aa)(1)(ii)(J) (J) Average mole fraction of CO2 in produced gas

1

Offshore Petroleum and 

Natural Gas Production

98.236(aa)(2) and

(aa)(2)(i)

(2) For offshore production, report the quantities specified in paragraphs 

(aa)(2)(i) and (aa)(2)(ii) of this section.

(i) The total quantity of gas handled at the offshore platform in the calendar 

year, in thousand standard cubic feet, including production volumes and 

volumes transferred via pipeline from another location.

1

Offshore Petroleum and 

Natural Gas Production

98.236(aa)(2)(ii) (ii) The total quantity of oil and condensate handled at the offshore platform 

in the calendar year for sales, in barrels, including production volumes and 

volumes transferred via pipeline from another location.

1

Onshore Natural Gas 

Processing

98.236(aa)(3) and

(aa)(3)(i)

(3) For natural gas processing, report the information specified in paragraphs 

(aa)(3)(i) through (aa)(3)(vii) of this section.

(i) The quantity of natural gas received at the gas processing plant in the 

calendar year, in thousand standard cubic feet.

1

Onshore Natural Gas 

Processing

98.236(aa)(3)(ii) (ii) The quantity of processed (residue) gas leaving the gas processing plant 

in the calendar year, in thousand standard cubic feet.

1

Onshore Natural Gas 

Processing

98.236(aa)(3)(iii) (iii) The cumulative quantity of all NGLs (bulk and fractionated) received at 

the gas processing plant in the calendar year, in barrels.

1

Onshore Natural Gas 

Processing

98.236(aa)(3)(iv) (iv) The cumulative quantity of all NGLs (bulk and fractionated) leaving the 

gas processing plant in the reporting year, in barrels.

1

Onshore Natural Gas 

Processing

98.236(aa)(3)(v) (v) Average mole fraction of CH4 in natural gas received.

1

Onshore Natural Gas 

Processing

98.236(aa)(3)(vi) (vi) Average mole fraction of CO2 in natural gas received.

1

Onshore Natural Gas 

Processing

98.236(aa)(3)(vii) (vii) Indicate whether the facility fractionates NGLs.

1

Onshore Natural Gas 

Transmission Compression

98.236(aa)(4) and

(aa)(4)(i)

(4) For natural gas transmission compression, report the quantity specified in 

paragraphs (aa)(4)(i) through (aa)(4)(v) of this section.

(i) The quantity of gas transported through the compressor station in the 

calendar year, in thousand standard cubic feet.

1

A-19
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Onshore Natural Gas 

Transmission Compression

98.236(aa)(4)(ii) (ii) Number of compressors.

1

Onshore Natural Gas 

Transmission Compression

98.236(aa)(4)(iii) (iii) Total compressor power rating of all compressors combined, in 

horsepower.

1

Onshore Natural Gas 

Transmission Compression

98.236(aa)(4)(iv) (iv) Average upstream pipeline pressure, in pounds per square inch gauge.

1

Onshore Natural Gas 

Transmission Compression

98.236(aa)(4)(v) (v) Average downstream pipeline pressure, in pounds per square inch gauge.

1

Underground Natural Gas 

Storage

98.236(aa)(5) and

(aa)(5)(i)

(5) For underground natural gas storage, report the quantities specified in 

paragraphs (aa)(5)(i) through (aa)(5)(iii) of this section.

(i) The quantity of gas injected into storage in the calendar year, in thousand 

standard cubic feet.

1

Underground Natural Gas 

Storage

98.236(aa)(5)(ii) (ii) The quantity of gas withdrawn from storage in the calendar year, in 

thousand standard cubic feet.

1

Underground Natural Gas 

Storage

98.236(aa)(5)(iii) (iii) Total storage capacity, in thousand standard cubic feet.

1

LNG Import and Export

Equipment

98.236(aa)(6) (6) For LNG import equipment, report the quantity of LNG imported in the 

calendar year, in thousand standard cubic feet.

1

LNG Import and Export 

Equipment

98.236(aa)(7) (7) For LNG export equipment, report the quantity of LNG exported in the 

calendar year, in thousand standard cubic feet.

1

LNG Storage 98.236(aa)(8) and

(aa)(8)(i)

(8) For LNG storage, report the quantities specified in paragraphs (aa)(8)(i) 

through (aa)(8)(iii) of this section.

(i) The quantity of LNG added into storage in the calendar year, in thousand 

standard cubic feet.

1

LNG Storage 98.236(aa)(8)(ii) (ii) The quantity of LNG withdrawn from storage in the calendar year, in 

thousand standard cubic feet.

1

LNG Storage 98.236(aa)(8)(iii) (iii) Total storage capacity, in thousand standard cubic feet.

1

Natural Gas Distribution 98.236(aa)(9) and

(aa)(9)(i)

(9) For natural gas distribution, report the quantities specified in paragraphs 

(aa)(9)(i) through (aa)(9)(vii) of this section.

(i) The quantity of natural gas received at all custody transfer stations in the 

calendar year, in thousand standard cubic feet. This value may include meter 

corrections, but only for the calendar year covered by the annual report.

1

Natural Gas Distribution 98.236(aa)(9)(ii) (ii) The quantity of natural gas withdrawn from in-system storage in the 

calendar year, in thousand standard cubic feet.

1

Natural Gas Distribution 98.236(aa)(9)(iii) (iii) The quantity of natural gas added to in-system storage in the calendar 

year, in thousand standard cubic feet.

1

Natural Gas Distribution 98.236(aa)(9)(iv) (iv) The quantity of natural gas delivered to end users, in thousand standard 

cubic feet. This value does not include stolen gas, or gas that is otherwise 

unaccounted for.

1

Natural Gas Distribution 98.236(aa)(9)(v) (v) The quantity of natural gas transferred to third parties such as other LDCs 

or pipelines, in thousand standard cubic feet. This value does not include 

stolen gas, or gas that is otherwise unaccounted for.

1

Natural Gas Distribution 98.236(aa)(9)(vi) (vi) The quantity of natural gas consumed by the LDC for operational 

purposes, in thousand standard cubic feet.

1

A-20
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import andExport EquipmentLNG Storage

Natural Gas Distribution 98.236(aa)(9)(vii) (vii) The estimated quantity of gas stolen in the calendar year, in thousand 

standard cubic feet. 1

TOTAL NUMBER OF NEW DATA ELEMENTS 247

TOTAL NUMBER OF NEW DATA ELEMENTS BY INDUSTRY 

SEGMENT

121 2 121 98 81 28 85 78

A-21
Table A-2. Revised Data Elements

Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import and Export EquipmentLNG Storage

Acid Gas Removal 98.236(d)(1)(ii) (ii) Total feed rate entering the acid gas removal unit, using a 

meter or engineering estimate based on process knowledge or 

best available data, in million cubic feet per year.

1 1

Acid Gas Removal 98.236(d)(2)(iii)(D) (D) Natural gas flow rate, in standard cubic feet per minute. 1 1

Well Venting for 

Liquids Unloading

98.236(f)(1)(iv) (iv) Count of wells vented to the atmosphere for the subbasin/well tubing diameter and pressure group. 1

Completions and 

Workovers with 

Hydraulic Fracturing

98.236(g)(5)(i) (i) The cumulative gas flowback time, in hours, from when gas 

is first detected until sufficient quantities are present to enable 

separation, and the cumulative flowback time, in hours, after 

sufficient quantities of gas are present to enable separation (sum 

of “Tp,i” and sum of “Tp,s” values used in Equation W-10A).

1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(1)(ii) (ii) Number of well completions that vented gas directly to the 

atmosphere without flaring. 1

Completions and 

Workovers without 

Hydraulic Fracturing

98.236(h)(2)(ii) (ii) Number of well completions that flared gas.

1

Onshore Production 

Storage Tanks

98.236(j)(2) and (j)(2)(i) and 

(j)(2)(i)(A)

(2) If you used Calculation Method 3 to calculate GHG 

emissions, then you must report the information specified in 

paragraph (j)(2)(i) through (j)(2)(iii) of this paragraph.

(i) Report the information specified in paragraphs (j)(2)(i)(A) 

through (j)(2)(i)(F) of this section at the basin level for 

atmospheric tanks where emissions were calculated using 

Calculation Method 3.

(A) The total annual oil throughput that is sent to atmospheric 

tanks in the basin, in barrels. You may delay reporting of this 

data element if you indicate in the annual report that wildcat 

wells and/or delineation wells are the only wells in the subbasin with oil production less than 10 barrels per day and that

send oil to atmospheric tanks. If you elect to delay reporting of 

this data element, you must report by the date specified in 

§98.236(cc) the total annual oil throughput from all wells and 

the API Well Number(s) for the wells included in this volume.

1

Centrifugal 

Compressors

98.236(o)(5) and

(o)(5)(i)

(5) Centrifugal compressors with wet seal degassing vents in 

onshore petroleum and natural gas production must report the 

information specified in paragraphs (o)(5)(i) through (o)(5)(iii) 

of this section.

(i) Number of centrifugal compressors that have wet seal oil 

degassing vents.

1 1 1 1 1

Reciprocating 

Compressors

98.236(p)(2)(ii)(D)(2) (2) Annual CH4 emissions, in metric tons CH4. 1 1 1 1 1

Equipment Leaks by 

Leak Detection

98.236(q)(1)(ii) (ii) Natural gas distribution facilities performing equipment leak 

surveys across a multiple year leak survey cycle must report the 

number of years in the leak survey cycle.

1

EOR Injection Pump 

Blowdown

98.236(w)(4) (4) Total volume of EOR injection pump system equipment 

chambers, in cubic feet (“Vv” in Equation W-37 of this 

subpart).

1

A-22
Emission Source Citation Reference Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import and Export EquipmentLNG Storage

Combustion 98.236(z)(1)(ii) (ii) The total number of combustion units. 1

Combustion 98.236(z)(2) and

(z)(2)(i)

(2) ... If the 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 Btu per hour (or the 

equivalent of 130 horsepower); or internal fuel combustion units 

of any heat capacity that are compressor-drivers, then you must 

report the information specified in paragraphs (z)(2)(i) through 

(z)(2)(vi) for each combustion unit type and fuel type 

combination.

(i) The type of combustion unit.

1

TOTAL NUMBER OF REVISED DATA ELEMENTS 13

TOTAL NUMBER OF REVISED DATA ELEMENTS BY 

INDUSTRY SEGMENT 8 0 4 2 2 3 2 2

A-23
Table A-3. Data Elements To Be Deleted

Emission Source Former Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import and Export EquipmentLNG Storage

Completions and Workovers with Hydraulic 

Fracturing

98.236(c)(6)(i)(G) Report number of completions employing purposely designed equipment 

that separates natural gas from the backflow and the amount of natural gas, in standard cubic 

feet, recovered using engineering estimate based on best available.

2

Completions and Workovers with Hydraulic 

Fracturing

98.236(c)(6)(i)(H) Report number of workovers employing purposely designed equipment that 

separates natural gas from the backflow and the amount of natural gas, in standard cubic feet, 

recovered using engineering estimate based on best available data.

2

Blowdown Vent Stacks 98.236(c)(7)(i)(A) Total number of blowdowns for each unique physical volume in the 

calendar year. 1 1 1

Blowdown Vent Stacks 98.236(c)(7)(i)(B) Annual CO2 and CH4 emissions, for each unique physical blowdown 

volume, expressed in metric tons CO2e for each gas. 2 2 2

Blowdown Vent Stacks 98.236(c)(7)(i)(C) A unique name or ID number for the unique physical volume. 1 1 1

Blowdown Vent Stacks 98.236(c)(7)(ii)(A) Total number of blowdowns for all unique physical volumes in the 

calendar year. 1 1 1

Blowdown Vent Stacks 98.236(c)(7)(ii)(B) Annual CO2 and CH4 emissions from all unique physical volumes as an 

aggregate per facility, expressed in metric tons CO2e for each gas. 2 2 2

Onshore Production Storage Tanks 98.236(c)(8)(i)(H) Best estimate of count of stock tanks assumed to have emissions control 

measures not at well pads, receiving your oil. 1

Onshore Production Storage Tanks 98.236(c)(8)(ii)(D) Sales oil API gravity range for wells in (c)(8)(ii)(B) and (c)(8)(ii)(C) of 

this section, in degrees. 1

Onshore Production Storage Tanks 98.236(c)(8)(ii)(F) Count of hydrocarbon tanks, both on and off well pads assumed to have 

emissions control measures: either vapor recovery system or flaring of tank vapors. 1

Onshore Production Storage Tanks 98.236(c)(8)(ii)(G) Annual CO2 and CH4 emissions that resulted from venting gas to the 

atmosphere, expressed in metric tons CO2e for each gas, at the sub-basin level for Calculation 

Methodology 3 or 4 of §98.233(j).

2

Onshore Production Storage Tanks 98.236(c)(8)(ii)(H) Annual CO2 and CH4 gas quantities that were recovered, expressed in 

metric tons CO2e for each gas, at the sub-basin level for Calculation Methodology 3 or 4 of 

§98.233(j).

2

Onshore Production Storage Tanks 98.236(c)(8)(ii)(I) Annual CO2, CH4, and N2O emissions that resulted from flaring gas, 

expressed in metric tons CO2e for each gas, at the sub-basin level for Calculation 

Methodology 3 and 4 of §98.233(j).

2

Onshore Production Storage Tanks 98.236(c)(8)(iii)(G) Annual CO2 and CH4 gas quantities that were recovered, expressed in 

metric tons CO2e for each gas, at the sub-basin level for Calculation Methodology 5 of 

§98.233(j).

2

Centrifugal Compressors 98.236(c)(13)(i)(B) Fraction of vent gas recovered for fuel or sales or flared. 1 1 1 1 1

Centrifugal Compressors 98.236(c)(13)(i)(C) Annual throughput in million scf, use an engineering calculation based on 

best available data. 1 1 1 1 1

Centrifugal Compressors 98.236(c)(13)(i)(D) Type of meters used for making measurements. 1 1 1 1 1

A-24
Emission Source Former Rule Text

Onshore Petroleum and Natural Gas ProductionOffshorePetroleum and Natural Gas ProductionOnshore Natural Gas ProcessingOnshore Natural Gas Transmission CompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import and Export EquipmentLNG Storage

Centrifugal Compressors 98.236(c)(13)(ii)(A) Total time in hours the compressor is in operating mode. 1 1 1 1 1

Centrifugal Compressors 98.236(c )(13)(iv) Report total annual compressor emissions from all modes of operation in 

metric tons of CO2e for each gas. 2 2 2 2 2

Reciprocating Compressors 98.236(c)(14)(i)(A) Annual throughput in million scf, use an engineering calculation based on 

best available data. 1 1 1 1 1

Reciprocating Compressors 98.236(c )(14)(iv) Report total annual compressor emissions from all modes of operation in 

metric tons of CO2e for each gas 2 2 2 2 2

Equipment Leaks by Leak Detection 98.236(c)(15)(i)(B) For onshore natural gas processing, range of concentrations of CH4 and 

CO2 (refer to Equation W-30A of §98.233). 2

Combustion Equipment for Onshore Petroleum 

and Natural Gas Production and Natural Gas 

Distribution Facilities

98.236(c)(19)(v) Cumulative number of internal fuel combustion units, not compressordrivers, with a rated heat capacity equal to or less than 1 mmBtu/hr or 130 horsepower, by type 

of unit.

1 1

TOTAL NUMBER OF DELETED DATA ELEMENTS 34

TOTAL NUMBER OF DELETED DATA ELEMENTS BY INDUSTRY SEGMENT 16 0 18 16 9 1 16 9

A-25