# Appendix A

List of Data Elements

Petroleum and Natural Gas Systems (Subpart W)

## Table A

- 1. New Data Elements

Emission Source Citation Reference Rule TextOnshorePetroleumand Natural GasProductionOffshorePetroleum andNatural GasProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import andExport EquipmentLNGStorage

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. 1 1 1

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. 1 1 1

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). 1 1 1

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 sec tion. 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 sulf ur recovery plant,

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

(d)(2) of this section. 1 1

Acid Gas Removal 98.236(d)(1)(iv) (iv) Whether any CO 2 emissions from the acid gas removal unit are

recovered and transferred outside the facility, according to §98.233(d)(11). 1 1

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 segment s only). 1 1

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

feet. 1 1

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

CO 2 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) Whi ch equation was used : Equation W

- 4A or W

- 4B. 1 1

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

CO 2 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 pa ckage used. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(B) (B) Natural gas feed temperature, in degrees Fahrenheit. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(C) (C) Natural gas feed pressure, in pounds per square inch. 1 1



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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 conta ins 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

segment s 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 wer e 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 regen erator

firebox/fire tubes. 1 1



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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 wer e vented to a vapor recovery device). 1 1

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) 2 2

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 de hydrator

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.) 2 2

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 g lycol 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) 1 1

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.) 1 1

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

dehydra tors venting to a flare or regenerator firebox/fire tubes.) 1 1

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



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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 w as 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



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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 sub

basin 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) V ented natural gas vol ume, 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 specifi ed 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 indicat e 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. 2 3 6 ( cc ) the measured average dail y gas production rate for

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

included in the measurement

. 1



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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. 2 3 6 ( 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

. ... 1 1 1

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

. ... 1 1 1

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

... 1 1 1

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 appo rtioned

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). 1 1 1

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). 1 1 1



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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). 1 1 1

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). 1 1 1

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). 1 1 1

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 applicabl e.

... 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



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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 th e 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 e lect to delay reporting of this data element , you

must report by the date specified in §98. 2 3 6 ( 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



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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) Indicat e whether any associated gas was vented directly to the

atmosphere without flaring. 1

Associated Natural Gas

Venting and Flaring 98.236(m)(3) (3) Indicat e 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 in dicate 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 volum e 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



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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 e lement 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 §98.2 36(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)(x i v) 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

- operating

depressurized

- 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



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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 c ompressor using as

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

compressor source. 1 1 1 1 1

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 t he 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

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. 1 1 1 1 1

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. 1 1 1 1 1

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

. 1 1 1 1 1

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. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(3)(i)(B) (B) Measurement date. 1 1 1 1 1

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. 1 1 1 1 1

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

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. 1 1 1 1 1

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. 1 1 1 1 1

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 E quation 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. 1 1 1 1 1



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Centrifugal Compressors 98.236(o)(3)(ii)(C) (C) The total number of compressors measured in the compressor mode

source combination in the current reporting year and the preceding two

reporting years ( “ Count m ” 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)(x i v) 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

- pressurized

mode. 1 1 1 1 1

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

- operating

depressurized

- 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



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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 o n 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



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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 Compressor s 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 E quation 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 mode

source combination in the current reporting year and the preceding two

reporting years ( “ Count m ” 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 ven t. 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) mu st 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, t he number of

complete equipment leak surveys performed during the calendar year. 1 1 1 1 1 1



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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 typ e 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. 1 1 1 1 1 1

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). 1 1 1 1 1 1

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 su rvey 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 (“Count MR ” 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 paragraph s (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 se ction 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.). 1 1 1 1 1

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. 1 1 1 1 1



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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)(i v ) (i v ) Average estimated time that each meter/regulator run at above grade

metering

- regulating stations that are not 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)(2)(v) (A) ( A ) Annual CO2 emissions, in metric tons CO2, from above grade metering

regulating 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 metering

regulating 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)(i i ) (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 th e 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



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- 17Emission Source Citation Reference Rule TextOnshorePetroleumand Natural GasProductionOffshorePetroleum andNatural GasProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import andExport EquipmentLNGStorage

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.

... 1 1

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: extern al fuel combustion

units with a rated heat capacity less than or equal to 5 m illion 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 13 0 horsepower)

. ... 1 1

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 m illion Btu per hour or internal fuel

combustion units that are not compressor

- drivers, with a rated heat capacity

less than or equal to 1 m illion 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. 1 1

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

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

fuel combustion units that are not compressor

- drivers, with a rated heat

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

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

compressor

- drivers.

... 1 1

Combustion 98.236(z)(2)(ii) (ii) The type of fuel combusted. 1 1

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

- 18Emission Source Citation Reference Rule TextOnshorePetroleumand Natural GasProductionOffshorePetroleum andNatural GasProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import andExport EquipmentLNGStorage

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



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- 19Emission Source Citation Reference Rule TextOnshorePetroleumand Natural GasProductionOffshorePetroleum andNatural GasProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import andExport EquipmentLNGStorage

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



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- 20Emission Source Citation Reference Rule TextOnshorePetroleumand Natural GasProductionOffshorePetroleum andNatural GasProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural GasDistributionLNG Import andExport EquipmentLNGStorage

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 2 4 7

TOTAL NUMBER OF NEW DATA ELEMENTS BY INDUSTRY

SEGMENT 1 2 1 2 1 21 9 8 81 2 8 8 5 7 8



# A

- 21

## Table A

- 2. Revised Data Elements

Emission Source Citation Reference Rule TextOnshorePetroleum andNatural GasProductionOffshorePetroleum andNatural GasProductionOnshoreNatural GasProcessingOnshoreNatural GasTransmissionCompressionUndergroundNatural GasStorageNatural GasDistributionLNG Importand ExportEquipmentLNG 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 sub

basin/well tubing diameter and pressure group. 1

Completions and

Workovers with

Hydraulic Fracturing 98.236(g)( 5)(i ) (i) T he 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 “T p,i ” and sum of “T

p,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) R eport 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 atmosph eric

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 sub

basin 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 th is 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

- 22Emission Source Citation Reference Rule TextOnshorePetroleum andNatural GasProductionOffshorePetroleum andNatural GasProductionOnshoreNatural GasProcessingOnshoreNatural GasTransmissionCompressionUndergroundNatural GasStorageNatural GasDistributionLNG Importand ExportEquipmentLNG 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 1 3

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 TextOnshore Petroleum andNaturalGas ProductionOffshorePetroleum and NaturalGas ProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import and ExportEquipmentLNG 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 estim ate 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



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- 24Emission Source Former Rule TextOnshore Petroleum andNaturalGas ProductionOffshorePetroleum and NaturalGas ProductionOnshore Natural GasProcessingOnshore Natural GasTransmissionCompressionUndergroundNatural Gas StorageNatural Gas DistributionLNG Import and ExportEquipmentLNG 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 compressor

drivers, 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 3 4

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



# A

- 25